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GEPowerManagement
DGP
Digital Generator Protection Relay™
Instruction Manual
DGP Revisions:V210.12000P
V210.10000F
V211.32000J
V210.22000D
Manual P/N: GEK-100666D
Copyright © 2000 GE Power Management
All relays must be powered up at least once per year
to avoid deterioration of electrolytic capacitors and
NOTE
GE Power Management
215 Anderson Avenue, Markham, Ontario
Canada L6E 1B3
Tel: (905) 294-6222 Fax: (905) 294-8512
Internet: http://www.GEindustrial.com/pm
subsequent relay failure.
Manufactured under an
ISO9002 Registered system.
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These instructions do not purport to co ve r all de tails o r variat ions in e quipment
g
g
g
nor provide for every possible contin
installation, operation, or maintenance. Should further information be desired
or should particular problems arise which are not covered sufficiently for the
purchaser’s purpose, the matter should be refe rred to the General Electric
Company.
To the extent required the products described herein meet applicable ANSI,
ency to be met in connection with
IEEE, and NEMA standards; but no such assurance is
local codes and ordinances because they vary
reatly.
iven with respect to
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TABLE OF CONTENTS
1. PRODUCT DESCRIPTION
1.1 GETTING STARTED
1.1.1 UNPACKING THE RELAY.........................................................................1-1
1.1.2 ORDER CODES & SELECTION GUIDE................................................... 1-2
1.1.3 SPECIAL MODELS....................................................................................1-3
DGP***AAA-0101 and DGP***AAA-0102....................................................... 1-3
DGP***ABA-0005 ...................................................................... .... .... .. .... .. .....1-3
1.1.4 DEC 1000 CONTACT EXPANSION UNIT.................................................1-3
1.2 INTRODUCTION
1.2.1 GENERAL..................................................................................................1-4
1.2.2 APPLICATION...........................................................................................1-4
1.3 PROTECTION FEATURES
1.3.1 DESCRIPTION.......................................................................................... 1-6
1.3.2 STATOR DIFFERENTIAL (87G)................................................................1-7
1.3.3 CURRENT UNBALANCE (46T)................ .................................................1-7
1.3.4 LOSS OF EXCITATION (40) ..................................................................... 1-7
1.3.5 ANTI-MOTORING (32)..............................................................................1-8
1.3.6 TIME OVERCURRENT WITH VOLTAGE RESTRAINT 51V.....................1-8
1.3.7 STATOR GROUND (64G/27TN)............................................................... 1-8
1.3.8 GROUND OVERCURRENT (51GN) ........................... ..............................1-9
1.3.9 OVEREXCITATION (24)............. .................................................. ............. 1-9
1.3.10 OVERVOLTAGE (59)..............................................................................1-10
1.3.11 UNDERVOLTAGE (27)......................... ...................................................1-10
1.3.12 OVER AND UNDERFREQUENCY (81)... ...............................................1- 1 0
1.3.13 VOLTAGE TRANSFORMER FUSE FAILURE (VTFF)............................ 1-10
1.3.14 ACCIDENTAL ENERGIZATION (AE)...................................................... 1-11
1.4 OTHER FEATURES
1.4.1 INPUTS....................................................................................................1-17
1.4.2 OUTPUT RELAYS.................................. ................................................. 1-17
1.4.3 START-UP SELF-TESTS ........................................................................1-18
1.4.4 RUN-TIME SELF-TESTS................ ........................................ ................. 1-18
1.4.5 ADAPTIVE SAMPLING FREQUENCY....................................................1-19
1.4.6 TRIP CIRCUIT MONITOR.................................................... ...................1-19
1.4.7 SEQUENCE OF EVENTS....................................... ......................... ....... 1-19
1.4.8 TIME SYNCHRONIZATION..................................................................... 1-20
1.4.9 FAULT REPORT & OSCILLOGRAPHY DATA........................................1-21
1.4.10 LOCAL MAN -MACHINE IN TERFACE............ .............. ............. .. ............ 1-21
1.4.11 LOCAL PRINTER ........................ .. .............. . .............. .. ............. .. ............ 1-21
1.4.12 REMOTE COMMUNICATIONS.......... .....................................................1-22
1.4.13 REMOTE CONTROL............................................................................... 1-22
1.4.14 PASSWORD PROTECTION........................... ......................... ............... 1-22
1.4.15 REMOTE COMMUNICATIONS – MODBUS PROTOCOL...................... 1-22
1.5 ELEMENTARY DIAGRAMS
2. CALCULATION OF
SETTINGS
2.1 GENERAL
2.1.1 DESCRIPTION.......................................................................................... 2-1
2.2 CONFIGURATION SETTINGS
2.2.1 DESCRIPTION........................................................................................ 2-10
101: UNITID – UNIT ID NUMBER ................................................................2-10
102: SYSFREQ – SYSTEM FREQUENCY .................................................. 2-10
103: SEL TVM – SELECT TRIP VOLTAGE MONITORING......................... 2-10
104: SEL TCM – SELECT TRIP CURRENT MONITORING........................ 2-10
105: SELPRIM – SELECT PRIMARY/SECONDARY UNITS .......................2-10
106: CT RATIO – CURRENT TRANSFORMER RATIO.............. .. ...............2-10
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TABLE OF CONTENTS
107: VT RATIO – VOLTAGE TRANSFORMER RATIO................................ 2-10
108: COMMPORT – COMMUNICATIONS PORT........................................ 2-11
109: PHASE – PHASE DESIGNATION........................................................ 2-11
110: TIMESYNC – TIME SYNCHRONIZATION SOURCE........................ ... 2-11
111: NUM FLTS – NUMBER OF FAULT EVENTS....................................... 2-11
112: PREFLT – PREFAULT CYCLES.......................................................... 2-12
113: OSC TRIG – EXTERNAL OSCILLOGRAPHY TRIGGER ....................2-12
114: NOM VOLT – NOMINAL VOLTAGE..................................................... 2-12
115: RATEDCUR – RATED CURRENT.......................................................2-12
116: VT CONN – VOLTAGE TRANSFORMER CONNECTION................... 2-12
117: NCTRATIO – NEUTRAL CURRENT TRANSFORMER RATIO ........... 2-12
2.2.2 EXAMPLE CONFIGURATION SETTINGS ..............................................2-12
2.3 PROTECTION FUNCTION SETTINGS
2.3.1 TRIP AND ALARM OUTPUT RELAYS .................................................... 2-13
2.3.2 STATOR DIFFERENTIAL 87G................................................................2-13
2.3.3 CURRENT UNBALANCE ALARM 46A....................................................2-18
2.3.4 CURRENT UNBALANCE TRIP 46T... ................... ............................... ... 2-18
2.3.5 LOSS OF EXCITATION 40, 40-1, 40-2 ...................................................2-20
2.3.6 ANTI-MOTORING (REVERSE POWER).................................................2-21
2.3.7 OVERCURRENT WITH VOLTAGE RESTRAINT (51V)..........................2-22
2.3.8 STATOR GROUND FAULT 64G-1.......................................................... 2-28
2.3.9 STATOR GROUND FAULT 64G-2.......................................................... 2-28
2.3.10 STATOR GROUND FAULT 27TN...........................................................2-28
2.3.11 OVEREXCITATION ALARM (VOLTS/HERTZ: 24A) ............................... 2-29
2.3.12 OVEREXCITATION TRIP (VOLTS/HERTZ: 24T).................................... 2-29
2.3.13 OVERVOLTAGE 59.................................................................................2-34
2.3.14 UNDERVOLTAGE CUTOFF OF 81......................................................... 2-36
2.3.15 UNDERFREQUENCY 81-U.....................................................................2-36
2.3.16 OVERFREQ U EN CY 81-O ......................... .. ........................................ .. .. 2-36
2.3.17 DIGITAL INPUT DI...................................................................................2-36
2.3.18 VOLTAGE TRANSFORMER FUSE FAILURE VTFF.............................. 2-37
2.3.19 ACCIDENTAL ENERGIZATION AE ........................................................ 2-37
2.3.20 GROUND OVERCURRENT 51GN................... ............................ ........... 2-38
2.3.21 UNDERVOLTAGE 27..............................................................................2-38
2.4 COMMISSIONING
2.4.1 DGP***AAA SETTINGS TABLE.............................................................. 2-41
2.4.2 DGP***ABA SETTINGS TABLE ..............................................................2-46
2.4.3 DGP***ACA SETTINGS TABLE ..............................................................2-51
3. HARDWARE
DESCRIPTION
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3.1 CASE ASSEMBLY
3.1.1 WARNING.................................................................................................. 3-1
3.1.2 CONSTRUCTION......................................................................................3-1
3.1.3 ELECTRICAL CONNECTIONS & INTERNAL WIRING............................ .3-1
3.1.4 IDENTIFICATION ......................................................................................3-1
3.2 CIRCUIT BOARD MODULES
3.2.1 WARNING.................................................................................................. 3-4
3.2.2 BASIC CONSTRUCTION.......................................................................... 3-4
3.2.3 IDENTIFICATION ...................................................... ................................3-4
3.3 XTM TEST PLUGS
3.3.1 DESCRIPTION .......................................................................................... 3-6
3.3.2 TERMINAL DESIGNATION........... .......................... ......................... ......... 3-6
3.3.3 XTM TEST-CIRCUIT CONNECTIONS....................................... ............... 3-6
3.3.4 T EST PL U G INSERTION ........... .. ........................................ .. ................... 3-6
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3.4 INSTALLATION
3.4.1 RECEIVING, HANDLING, & STORAGE.................................................... 3-7
3.4.2 ENVIRONMENT........................................................................................ 3-7
3.4.3 MOUNTING ............................................................................................... 3-7
3.4.4 EXTERNAL CONNECTIONS..... ......................... ......................... ............. 3-7
3.4.5 EXTERNAL CONNECTIONS TEST..........................................................3-7
3.4.6 SURGE GROUND CONNECTIONS.................... ........................... ........... 3-7
4. ACCEPTANCE TESTS
4.1 INTRODUCTION
4.1.1 WARNING..................................................................................................4-1
4.1.2 GENERAL..................................................................................................4-1
a GENERAL TESTS.....................................................................................4-1
b PROTECTION TESTS................ ......................... ......................... ............. 4-1
4.2 TEST PREPARATION
4.2.1 TEST EQUIPMENT...................................................................................4-2
4.2.2 DRAWINGS & REFERENCES..................................................................4-2
a DRAWINGS............................................................................................... 4-2
b REFERENCES..........................................................................................4-2
4.2.3 EQUIPMENT GROUNDING......................................................................4-2
4.2.4 REQUIRED SETTINGS......... .......................... ......................... ................. 4-2
4.3 GENERAL INSTRUCTIONS
4.3.1 PROCEDURE............................................................................................4-3
4.3.2 SETTING CHANGES................................................................................. 4-3
4.3.3 ENTERING THE TEST MODE.................................................................. 4-4
4.3.4 EXITING THE TEST MODE......................................................................4-4
4.4 USING GE-LINK
4.4.1 DESCRIPTION.......................................................................................... 4-5
4.4.2 HARDWARE SETUP................................................................................. 4-5
4.4.3 SO FTWARE SETU P........... .. ............. .. .. ............. .. ............. .. .. .................... 4-5
a LOAD & START GE-LINK..........................................................................4-5
b SET UP A NEW TEST UNIT......................................................................4-5
4.4.4 RELAY SETUP.......................................................................................... 4-6
4.4.5 LOGGING INTO THE RELAY....................................................................4-6
4.4.6 SETTING CHANGES................................................................................. 4-7
4.4.7 ENTERING THE TEST MODE.................................................................. 4-7
4.4.8 EXITING THE TEST MODE......................................................................4-7
4.5 INITIAL TEST SETUP
4.5.1 DESCRIPTION.......................................................................................... 4-8
4.6 GENERAL RELAY TESTS
4.6.1 NOTE......................................................................................................... 4-9
4.6.2 T1: MMI STATUS AND DISPLAY TESTING.............................................4-9
a STATUS CHECK ....................................................................................... 4-9
b WARNING STATUS .................................................................................. 4-9
c DISPLAY TEST........................................................................................ 4-10
4.6.3 T2: DIGITAL OUTPUT TESTS ................................................................4-11
4.6.4 T3: DIGITAL INPUT TESTS ....................................................................4-13
4.6.5 T4: AC SYSTEM INPUT TEST ................................................................ 4-15
4.7 PROTECTION TESTS
4.7.1 DESCRIPTION........................................................................................ 4-17
4.7.2 T5: GENERATOR DIFFERENTIAL TEST 87G.......................................4-18
4.7.3 T6: CURRENT UNBALANCE ALARM 46A ............................................. 4-20
4.7.4 T7: CURRENT UNBALANCE TRIP 46T.................................................. 4-20
4.7.5 T8: LOSS OF FIELD PROTECTION ZONE 1 40-1.................................4-22
4.7.6 T9: LOSS OF FIELD PROTECTION ZONE 2, 40-2................................4-23
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4.7.7 T10: ANTI-MOTORING & SEQUENTIAL TRIP SUPERVISION 32-1 ..... 4-23
4.7.8 T11: ANTI-MOTORING 32-2 ................................................................... 4-24
4.7.9 T12: TIME OVERCURRENT WITH VOLTAGE RESTRAINT 51V ..........4-24
4.7.10 T13: ACCIDENTAL ENERGIZA TION AE ................................................ 4-25
4.7.11 T14: STATOR GROUND ZONE 1 64G1 ................................................. 4-27
4.7.12 T15: STATOR GROUND ZONE 2 64G2 ................................................. 4-28
4.7.13 T16: VOLTS/HERTZ OVEREXCITATION ALARM 24A..........................4-30
TEST RESULTS:..........................................................................................4-30
4.7.14 T17: VOLTS/HERTZ OVEREXCITATION TRIP 24T...............................4-31
4.7.15 T18: POSITIVE-SEQUENCE OVERVOLTAGE 59..................................4-32
TEST RESULTS...........................................................................................4-32
4.7.16 T19: UNDERFREQUENCY UNIT #1 81-1U ............................................4-33
4.7.17 T20: UNDERFREQUENCY UNIT #2 81-2U ............................................4-33
4.7.18 T21: UNDERFREQUENCY UNIT #3 81-3U ............................................4-34
4.7.19 T22: UNDERFREQUENCY UNIT #4 81-4U ............................................4-34
4.7.20 T23: OVERFREQUENCY UNIT #1 81-1O ...............................................4-35
4.7.21 T24: OVERFREQUENCY UNIT #2 81-2O ...............................................4-35
4.7.22 T25: OVERFREQUENCY UNIT #3 81-3O ...............................................4-36
4.7.23 T26: OVERFREQUENCY UNIT #4 81-4O ...............................................4-36
4.7.24 T27: VOLTAGE TRANSFORMER FUSE FAILURE VTFF ...................... 4-37
4.7.25 T28: TOC GROUND OVERCURRENT 51GN.........................................4-37
4.7.26 T29: UNDERVOLTAGE 27......................................................................4-38
4.7.27 T30: THIRD HARMONIC NEUTRAL UNDERVOLTAGE 27TN...............4-38
4.8 END OF ACCEPTANCE TESTING
4.8.1 DESCRIPTION ........................................................................................ 4-40
5. PERIODIC TESTS
5.1 INTRODUCTION
5.1.1 DESCRIPTION .......................................................................................... 5-1
5.1.2 GENERAL TESTS.....................................................................................5-1
5.1.3 PROTECTION FUNCTION TESTS.... ...................................................... .5-1
5.1.4 GENERAL INSTRUCTIONS......................................................................5-1
5.2 RELAY TESTS
5.2.1 T1: RELAY STATUS & MMI ......................................................................5-2
a STATUS CHECK......................... ................................................... ........... 5-2
b DISPLAY TEST..........................................................................................5-2
5.2.2 T2: DIGITAL OUTPUT TEST.....................................................................5-3
5.2.3 T3: DIGITAL INPUT TEST......................................................................... 5-4
5.2.4 T4: AC SYSTEM INPUT TEST ..................................................................5-5
5.3 MEASURING UNIT TESTS
5.3.1 DESCRIPTION .......................................................................................... 5-6
5.3.2 T5: GENERATOR DIFFERENTIAL TEST 87G ......................................... 5-6
5.3.3 T6: CURRENT UNBALANCE ALARM 46A ...............................................5-6
5.3.4 T7: CURRENT UNBALANCE TRIP 46T....................................................5-7
5.3.5 T8: LOSS OF EXCITATION 40-1 ..............................................................5-8
5.3.6 T9 ANTI-MOTORING TEST 32-1............................................ ..................5-9
5.3.7 T10: TIME OVERCURRENT WITH VOLTAGE RESTRAINT 51V ..........5-10
5.3.8 T11: STATOR GROUND ZONE 1 64G1 ................................................. 5-11
5.3.9 T12: STATOR GROUND ZONE 2 64G2 ................................................. 5-11
5.3.10 T13: VOLTS/HERTZ OVEREXCITATION ALARM 24A..........................5-12
5.3.11 T14: VOLTS/HERTZ EXCITATION TRIP 24T......................................... 5-13
5.3.12 T15: POSITIVE-SEQUENCE OVERVOLTAGE 59..................................5-14
5.3.13 T16: UNDERFREQUENCY UNIT #1 81-1U ............................................5-14
5.3.14 T17: OVERFREQUENCY UNIT #1 81-1O ...............................................5-15
5.3.15 T18: VOLTAGE TRANSFORMER FUSE FAILURE VTFF ...................... 5-15
5.3.16 T19: TOC GROUND OVERCURRENT 51GN.........................................5-16
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5.3.17 T20: POSITIVE-SEQUENCE UNDERVOLTAGE 27...............................5-17
5.4 END OF PERIODIC TESTING
5.4.1 ENDING PERIODIC TESTS.................................................................... 5-18
6. SERVICING
7. SPECIFICATIONS
8. INTERFACE
6.1 SPARES
6.1.1 DESCRIPTION.......................................................................................... 6-1
6.2 RELAY SELF-TESTS
6.2.1 DESCRIPTION.......................................................................................... 6-2
6.3 TROUBLESHOOTING
6.3.1 DESCRIPTION.......................................................................................... 6-4
6.3.2 USING THE INFORMATION STATUS COMMAND.................................. 6-4
6.3.3 SERVICING A CRITICAL FAILURE FAIL.................................................. 6-5
6.3.4 SERVICING A NON-CRITICAL FAILURE WARN.....................................6-5
6.3.5 SERVICING SYSTEM STATUS FAILURES ..............................................6-6
6.4 ERROR CODES
6.4.1 ERROR MESSAGES AT STARTUP .........................................................6-7
6.4.2 ERROR MESSAGES AT RUNTIME.......................................................... 6-9
7.1 DGP SPECIFICATIONS
7.1.1 DESCRIPTION.......................................................................................... 7-1
7.1.2 PROTECTION FUNCTIONS AND SETTING RANGES............................ 7-2
8.1 DISPLAY
8.1.1 DESCRIPTION.......................................................................................... 8-1
8.2 TARGET LEDs & TARGET RESET KEY
8.2.1 TARGET LEDs...........................................................................................8-2
8.2.2 TARGET RESET KEY...............................................................................8-2
8.3 KEYPAD
8.3.1 DESCRIPTION.......................................................................................... 8-3
8.3.2 CLEAR KEY [CLR]..................................................................................... 8-3
8.3.3 PRINT KEY [PRT]...................................................................................... 8-4
8.3.4 ARROW KEYS...........................................................................................8-4
8.3.5 ENTER KEY [ENT]........................... .........................................................8-4
8.3.6 DATA ENTRY KEYS........................................ ..........................................8-4
8.3.7 END KEY [END].........................................................................................8-5
8.3.8 SETTINGS KEY [SET]...............................................................................8-5
8.3.9 ACTIONS KEY [ACT]................................................................................. 8-7
1. DISABLE OUTPUTS.................................................................................. 8-7
2. ENABLE OUTPUTS................................................................................... 8-7
3. TRIP............................................................................................................ 8-8
4. RESET........................................................................................................ 8-8
5. DATE/TIME.................. .. ............. .............. .. ............. ............. .. .............. ...... 8-8
6. RELAY TEST..............................................................................................8-9
7. MMI TEST...................................................................................................8-9
8. FIX UP SETTINGS CRC ............................................................................ 8-9
9. ENTER PASSWORD................................................................................ 8-10
10. CHANGE PASSWORD..........................................................................8-10
11. DIGITAL OUTPUT TEST........................................................................8-10
...................................................................................................................... 8-11
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8.3.10 INFORMATION KEY [INF].. .. ........................... .. ...................................... 8-12
1. REQUEST DGP STATUS.........................................................................8-12
2. REQUEST FAULT INFORMATION..........................................................8-12
3. REQUEST PRESENT VALUES ...............................................................8-13
4. REQUEST EVENTS.................................................................................8-13
5. VIEW PASSWORD................................................................................... 8-13
6. REQUEST DGP MODEL/VERSION.........................................................8-13
7. STATION ID..............................................................................................8-13
8. GENERATOR ID.......................................................................................8-13
8.4 ERROR MESSAGES
8.4.1 DESCRIPTION ........................................................................................ 8-15
8.5 PASSWORDS
8.5.1 DESCRIPTION ........................................................................................ 8-16
8.5.2 ENCRYPTED PASSWORD CONVERSION TABLE...............................8-17
9. COMMUNICATIONS
9.1 INTRODUCTION
9.1.1 HARDWARE JUMPERS............................................ ................................ 9-1
9.1.2 MODEM CONNECTIONS & SETTINGS...................................................9-1
9.1.3 PC MODEM............................................................................................... 9-1
9.1.4 DGP MODEM ............................................................................................ 9-2
9.1.5 NULL MODEM CONNECTIONS ...............................................................9-2
9.1.6 RS485 COMMUNICATIONS ....... .......................... .................................... 9-4
9.2 MODBUS COMMUNICATIONS
9.2.1 INTRODUCTION ....................................................................................... 9-5
9.2.2 DATA FRAME FORMAT & DATA RATE...................................................9-5
9.2.3 DATA PACKET FORMAT..................................................... .....................9-5
a SLAVE ADDRESS.....................................................................................9-5
b FUNCTION CODE.....................................................................................9-6
c DATA ......................................................................................................... 9-6
d CRC HI & CRC LO.....................................................................................9-6
9.2.4 ERROR CHECKING..................................................................................9-6
9.2.5 DATA FRAMING.................... ............................................................. ....... 9-6
9.3 MODBUS FUNCTIONS
9.3.1 FUNCTION CODE 03/04: READING HOLDING/INPUT REGISTERS......9-7
a DESCRIPTION .......................................................................................... 9-7
b QUERY...................................................................................................... 9-7
c RESPONSE............................................................................................... 9-7
9.3.2 FUNCTION CODE 05: FORCE SINGLE COIL........................................ .. 9-8
a DESCRIPTION .......................................................................................... 9-8
b QUERY...................................................................................................... 9-8
c RESPONSE............................................................................................... 9-8
9.3.3 FUNCTION CODE 06: STORE SINGLE SETPOINT................................9-9
a DESCRIPTION .......................................................................................... 9-9
b QUERY...................................................................................................... 9-9
c RESPONSE............................................................................................... 9-9
9.3.4 FUNCTION CODE 16: PRESET MULTIPLE SETPOINTS......................9-10
a DESCRIPTION ........................................................................................ 9-10
b QUERY.................................................................................................... 9-10
c RESPONSE............................................................................................. 9-10
9.3.5 FUNCTION CODE 56: RETRANSMIT LAST PACKET...........................9-10
a DESCRIPTION ........................................................................................ 9-10
b QUERY.................................................................................................... 9-10
c RESPONSE............................................................................................. 9-10
9.4 MODBUS ERRORS
9.4.1 ER ROR RESPONS ES...... .............. . .. .............. .. .. ............. .. ............. .. .. .... 9-11
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9.5 MODBUS MEMORY MAPPING
9.5.1 DATA TYPES.................................. .........................................................9-12
9.5.2 MEMORY MAP ORGANIZATION............................................................9-1 3
9.5.3 FIXED VALUE INPUT REGISTERS........................................................9-13
9.5.4 PRESENT VALUE REPORT REGISTER MA P.......................................9 - 13
9.5.5 EVENT REPORT MEMORY MAP........................................................... 9-14
9.5.6 FAULT STATUS MEMORY MAP ............................................................ 9-14
9.5.7 FAULT REPORT REGISTER MAP .........................................................9-14
9.5.8 OSCILLOGRAPHY REPORT MEMORY M AP ........................................ 9-15
a CONTROL REGISTERS................................ ......................... ................. 9-15
b OSCILLOGRAPHY HEADER..................................................................9-15
c OSCILLOGRAPHY SETTINGS............................................................... 9-15
d OSCILLOGRAPHY DATA........................................................................ 9-16
e COMMUNICATION EXAMPLE................................................................ 9-16
9.5.9 EVENT CODES & STATUS REGISTERS...............................................9-17
a EVENT CODES.......................................................................................9-17
b SP (STATUS) REGISTERS..................................... ................................ 9-20
c OSC SETTINGS......................................................................................9-23
9.5.10 MMI PASSWORDS.................................................................................. 9-24
9.5.11 SETTINGS ............................................................................................... 9-24
9.5.12 STATION & GENERATOR ID REGISTER MAP .....................................9-24
9.5.13 DATE & TIME............................. .............................................................9-24
9.5.14 MEMORY MAP..................................... ................................................... 9-25
9.6 COIL COMMANDS
9.6.1 DESCRIPTION........................................................................................ 9-49
9.7 FACTORY SETTINGS (GE FACTORY TESTS ONLY)
9.7.1 DESCRIPTION........................................................................................ 9-50
10. GE-LINK SOFTWARE
10.1 INTRODUCTION
10.1.1 OVERVIEW.............................................................................................. 10-1
10.1.2 SYSTEM REQUIREMENTS................. ......................... ..........................10-1
a HARDWARE..................................... ......................... ......................... ..... 10-1
b SOFTWARE.................................. ......................... ......................... ......... 10-1
10.1.3 INSTALLATION... ......................... ......................... ......................... ......... 10-1
10.2 GENERAL OPERATION
10.2.1 PROTECTION JUMPERS.................. ......................... ......................... ...10-2
10.2.2 GE-LINK USER INTERFACE.................................................................. 10-2
10.2.3 ADDING/MODIFYING A SITE (LOCATION) ........................................... 10-2
10.2.4 DELETING A SITE (LOCATION)............................................................. 10-3
10.3 IED CONNECTION
10.3.1 SERIAL CONNNECTION.... ................................................... ................. 10-4
10.3.2 MODEM CONNECTION ..........................................................................10-4
10.3.3 IED MODES................... ......................... ......................... ........................10-5
10.3.4 ADDING/M O D Y F YING AN IED ............. ............. ........................... .......... 10-5
a ADDING AN IED................... .. ............. .. ............. .. ............. .. .............. ...... 10-5
b MODIFYING IED PROPERTIES.............................................................10-6
c DELETING AN IED..................................................................................10-6
10.3.5 RETREIVING INFORMATION.................................................................10-6
10.4 MANIPULATING SETTINGS
10.4.1 EDIT MODE............................................................... ......................... ..... 10-8
10.4.2 SETTINGS MODE................................................................................... 10-8
10.5 PERFORMING OPERATIONS
10.5.1 DESCRIPTION........................................................................................ 10-9
10.5.2 CHANGE PASSWORD........ .......................... .......................................... 10-9
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10.5.3 MANUAL TRIP........................................................... .............................. 10-9
10.5.4 ENABLE OUTPUTS.......................................................................... ....... 10-9
10.5.5 DISABLE OUTPUTS................................................................................10-9
10.5.6 CHANGE DATE & TIME........................................................................ 10-10
10.5.7 CHANGE GENERATOR/STATION ID................................. ..................10-10
10.5.8 RELAY TEST.........................................................................................10-10
10.5.9 DIGITAL OUTPUT TEST....................................................................... 10-10
10.5.10 DIGITAL RESET.................................................................................... 10-10
10.6 GETTING INFORMATION
10.6.1 DESCRIPTION ......................................................................................10-11
10.6.2 PRESENT VALUES...............................................................................10-11
10.6.3 FAULT REPORT IDENTIFICATION ...................................................... 10-11
10.6.4 FAULT REPORT.................................................................................... 10-11
10.6.5 EVENTS LOG........................................................................................10-11
10.6.6 OSCILLOGRAPHY DATA......................................................................10-12
10.6.7 DGP STATUS........................................................................................ 10-12
10.6.8 DGP MODEL .........................................................................................10-12
10.6.9 STATION/GENERATOR ID...................................................................10-12
10.6.10 MMI PASSWORD..................................................................................10-12
A. TABLES AND FIGURES
B. REVISIONS
C. DGP FAQ
D. WARRANTY
A.1 TABLES AND FIGURES
A.1.1 LIST OF TABLES.......................................................................................A-1
A.1.2 LIST OF FIGURES ........ ......................... ......................... ......................... .A-1
B.1 CHANGE NOTES
B.1.1 REVISION HISTORY.................................................................................B-1
B.1.2 ADDITIONS TO DGP MANUAL..................................... ......................... ...B-1
B.1.3 CHANGES TO DGP MANUAL..................................................................B-3
C.1 DGP FAQ
C.1.1 FREQUENTLY ASKED QUESTIONS .......................................................C-1
C.1.2 NOT-SO-FREQUENTLY ASKED QUESTIONS ........................................C-4
D.1 DGP WARRANTY
viii
DGP Digital Generator Protection System
GE Power Management
Page 13
1 PRODUCT DESCRIPTION 1.1 GETTING STARTED
1 PRODUCT DESCRIPTION 1.1 GETTING STARTED 1.1.1 UNPACKING THE RELAY
The following procedure describes how to unpack and setup the DGP.
1. Unpack and examine the DGP Digita l Generator Protection relay. Ensure each module is properly s eated
in the relay prior to applying power.
2. Apply rated DC power to the relay at the power supply input terminals. Refer to the appropriate elementary
diagram in Section 1 .5: ELE MENTARY DIAGRAMS on page 1–23 for th e loca tion of these t ermin als. Th e
rated DC value (Vps) fo r the relay is found on the na meplate located inside the fr ont cover on the right
side.
3. The DGP settings and control functions are protected by passwords on both MMI and remote access. The
relay is shipped with the factory default passwords that mus t be changed before any setting change or
control command can be executed (GE Modem Version only). The default passwords are listed below:
MODE PAS SWORD
MMI - SETTING 1234.
MMI - MASTER 5678.
REMOTE LINK - VIEW VIEW!
REMOTE LINK - SETTING SETT!
REMOTE LINK - CONTROL CTRL!
Note that the characters "." and "!" are part of the default passwords.
1
4. Instructions on how to use the key pa d to ch ang e s etti ng s a nd p ut t he r elay i nto t es t mo de c an be foun d i n
Section 4.3.2: SETTING CHANGES on page 4–3. Complete instructions on how to operate the keypad are
found in Section 8.3: KEYPAD on page 8–3.
5. To communicate with the relay from a PC, connect the relay to a serial port of an IBM compatible computer
with a DGP null-mode m cable. Connectio n can be made either to the 25 pin D- connector on the b ack of
the relay (PL-1) or the 9 pin D-connector on the front (COM).
6. Refer to Figure 9–1: DGP COMMUNICATIONS WIRING on page 9–3 for the internal wiring of the cable.
7. GE-Link, the communicatio ns software required to access the relay from a PC, is included on the GE
Power Management Pr oduct s CD or avail able f rom the G E P ower Man agement web s ite at www.ge.com/
indsys/pm. Follow instructions in 10.1.3: INSTALLATION on page 10–1 to load GE-Link onto the PC.
8. To log into the relay, follow the instructions in Section 4.4: USING GE-LINK on page 4–5.
9. This instruction book describes functions available in DGP models with standard function groups A, B, and
C. Refer to the Nomenclature Sel ection Guide sh own below to determine func tions included in a specific
model.
GE Power Management DGP Digital Generator Protection System 1-
1
Page 14
1.1 GETTING STARTED 1 PRODUCT DESCRIPTION
g
g
1
Table 1–1: ORDER CODES
Base Unit
Current Rating
Power Supply
Test Blocks
Protocol
Functions and
Features
Revision
DGP
DGP
* * *
||||||
1
5
0
1
2
3
4
Table 1–2: DGP SELECTION GUIDE
FUNCTIONS & FEATURES A B C
Stator Differential 87G
Current Unbalance 46
Loss of Exc itation 40-1, 40-2
Anti-motorin
Overcurrent Volta
Stator Ground 64G1
Stator Ground 64G2
Stator Ground 27TN
Neutral Overcurrent 51GN Overexcitation 24 (Volts/Hz)
Overvoltage 59
Undervoltage 27 Underfrequency 81-U 424
Overfrequency 81-O 422
Accidental Engergization Logic
Sequential Trip Logic
Voltage Transformer Fuse Failure VTFF
Oscillography Data Capture
RS232 Communications Ports 222
Printer Output
IRIG-B Input
DEC1000 compatible --
c
64G1 is Fundamental Frequency Overvoltage, also known as 59GN
d
64G2 uses 3rd harmonic comparator algorithm for enhanced security
e
27TN is 3rd Harmonic Undervoltage supervised by an adjustable window of forward power.
32
e Restraint 51V
c
d
e
| | | | |
| | | | |
||||
||||
||||
||||
||||
| | |
A
| | |
B
||
A
||
B
A
B
C
1.1.2 ORDER CODES & SELECTION GUIDE
Base Unit
1 Ampere Rated Current
5 Ampere Rated Current
One Power Supply, 48 V DC
One Power Supply, 110 to 125 V DC
One Power Supply, 220 to 250 V DC
Two Power Supplies, 4 8 V DC
Two Power Supplies, 110 to 125 V DC
With T est Blocks
Without Te st Blocks
GE Modem Protocol
Modbus RTU Protcol (DGP***BCA only)
Functions and Features – see DGP selection guide below.
|
|
|
DGP Revision A Firmware
A
✔✔✔
✔✔✔
✔✔✔
212
✔✔✔
✔✔✔
✔
-
✔✔✔
✔✔✔
✔✔✔
✔✔✔
✔✔✔
✔✔✔
✔
✔✔✔
-
✔
✔✔
✔✔
✔✔
-
✔
✔
1-
2
DGP Digital Generator Protection System GE Power Management
Page 15
1 PRODUCT DESCRIPTION 1.1 GETTING STARTED
1.1.3 SPECIAL MODELS
In addition to the stan dard D GP model descri bed by the order codes a bove, s everal specia l mo dels ar e available. Some of these are shown below with a brief description.
DGP***AAA-0101 and DGP***AAA-0102
This model is similar to the standard DGP***AAA except for the following major changes:
• All digital inputs are rated for nominal voltage of 110 to 125 V DC instead of the standard 48 to 250 V DC
• The logic for function 51V is modified to remove fault detector supervision
• Seperate terminals are provided for the optional second power supply input
Refer to instruction book GEK-105552 for additional detail.
DGP***ABA-0005
This model is similar to the standard DGP***ABA except for the following major changes:
• Includes the Stator Ground 27TN function
• Includes oscillography data capture and IRIG-B input capabilities
• Suitable for application with 208 V AC nominal input
Refer to instruction book GEK-105587 for additional detail.
1.1.4 DEC 1000 CONTACT EXPANSION UNIT
1
The DEC 1000 is a relay expan sion unit for the DGP consisti ng of five form C relays and six form A relays.
These contacts can be used for signalling or alarm purposes. Any protection function available in the companion DGP relay can be sele cted for DEC output relay assignment. T he DEC 1000 is connected via the DGP
printer port PL2.
The DEC 1000 expansion unit is only compatible with the DGP
NOTE
kkkkk
C units.
GE Power Management DGP Digital Generator Protection System 1-
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Page 16
1.2 INTRODUCTION 1 PRODUCT DESCRIPTION
1.2 INTRODUCTION 1.2.1 GENERAL
1
The DGP Digital Generator Protection™ System is a microprocessor-based digital relay system that uses
waveform sampling of curren t and voltage inputs to provide protecti on, control and monitoring of gener ators.
These samples are used to compute current and vol tage phasors that are used for the protection-function
algorithms. The DGP™ system uses a man-machine interface (MMI) and GE-Link software for local and
remote communication respectively.
This instruction book describes all the functions available in the various standard DGP models. Refer
to the SELECTION GUIDE in the previous section to determine functions included in a specific model.
1.2.2 APPLICATION
The DGP system is designed to be used on hydroelectric, gas, and steam generating units. Any size of generator can be protected with this digital system.
More detailed appl ication cons ider ations are contai ned b elow i n the rem aining head ings of this sec tion and i n
Chapter 2: CALCULATION OF SETTINGS.
A typical wiring diagram for the DGP relay is shown on the following page.
1-
4
DGP Digital Generator Protection System GE Power Management
Page 17
1 PRODUCT DESCRIPTION 1.2 INTRODUCTION
PRINTER
or
DEC1000
Contact Expansion
Unit
GROUND
BUS
RS-232
RS-232
PRINTER
IRIG-B
CONTROL
POWER
g
AH
AH
AH
AH
1
2
3
4
IBR IBS
IAR
GE Power Management
AG1
AG2
AH
12
VOLT
BH
14
GND
AH
11
DGP
Digital Generator Protection
BG
8
GENERATOR
BG
OFF LINE
7
BG
TURBINE
6
INLET VALVE
BG
LIMIT SWITCH
5
BG
EXTERNAL
4
TRIP 1
BG
3
BG
2
BG
1
BE
4
BE
3
BE
2
BE
1
OSCILLOGRAPH
Disable Prot.
DB9
DB25
DB25
EXTERNAL
TRIP 2
TRIGGER
EXT. VTFF/
(REAR)
(FRONT)
(REAR)
(REAR)
PL3
TS
PU
IN
PL1
PL2
A
C(B)
B(C)
BH
BH
BH
AH
AH
AH
AH
5
6
7
8
ICR ICS
INR INS
CURRENT
INPUTS
BH
1
2
3
4
IAS
A
B
C
BH
BH
BH
BH
BH
BH
BH
8
5
6
7
94G
94G1
94G2
94G3
74A
74B
74C
S
T
U
P
T
U
O
74D
74FF
DOR 12
DOR 13
DOR 9
74 NC
74 CR
POWER
SUPPLY
ALARM 1
POWER
SUPPLY
ALARM 2
9
10
VA
VOLTAGE
TRIP A
(DRY)
TRIP A
TRIP B
(DRY)
TRIP B
TRIP C
(DRY)
TRIP C
TRIP D
(DRY)
TRIP D
ALARM A
ALARM B
ALARM C
ALARM D
VT FUSE FAIL
TEST PICKUP
TEST TRIP
SPARE
SELF TEST
NON
CRITICAL
SELF-TEST
CRITICAL
BH
AH
11
12
9
VB
704753A7.CDR
AH
10
VC
BE
10
BF
10
BE
(+)
14
BF
(-)
14
BE
9
BF
9
BE
(+)
13
BF
(-)
13
BE
8
BF
8
BE
(+)
12
BF
(-)
12
BE
7
BF
7
BE
(+)
11
BF
(-)
11
AG
14
AF
14
AE
14
AG
13
AF
13
AE
13
AG
12
AF
12
AE
12
AG
11
AF
11
AE
11
AG
10
AF
10
AE
10
AG
6
AF
6
AE
6
AG
5
AF
5
AE
5
AG
9
AF
9
AE
9
AG
8
AF
8
AE
8
AG
7
AF
7
AE
7
BF
5
BE
5
BF
BF
6
6
BE
BF
6
6
1
Figure 1–1: TYPICAL WIRING DIAGRAM
GE Power Management DGP Digital Generator Protection System 1-
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Page 18
1.3 PROTECTION FEATURES 1 PRODUCT DESCRIPTION
1.3 PROTECTION FEATURES 1.3.1 DESCRIPTION
1
The following protection functions are included with the DGP system.
Table 1–3: DGP PROTECTION FUNCTIONS
PROTECTION FUNCTION ANSI CODE(S)
Stator Differential 87G
Current Unbalance 46
Loss of Excitation 40
Anti-Motoring 32
Time Overcurrent with Voltage Restraint 51V
Stator Ground 64G1, 64G2, 27TN
Ground Overcurrent 51GN
Over-excitation 24
Overvoltage 59
Undervoltage 27
Over and Underfrequency 81
Voltage Transformer Fuse Failure VTFF
Accidental Energization AE
A single-line diagram for the DGP is shown below.
GEN.
51GN
27NT
64G2
64G1
RS232
87G
VTFF
51V
32
RS232
40
46
24
VTFF
64G2
51V
GSU
Transf.
32
40
27
59
52G
81
TO
POWER
SYSTEM
DGP
1-
To
MODEM
To
ALARM
LAPTOP
PC
TRIP
Figure 1–2: SINGLE LINE DIAGRAM
6
DGP Digital Generator Protection System GE Power Management
Page 19
1 PRODUCT DESCRIPTION 1.3 PROTECTION FEATURES
1.3.2 STATOR DIFFERENTIAL (87G)
This function provides high -speed pr otection of the genera tor stat or during inter nal pha se-to- phase an d threephase faults. It uses a product-restraint algorithm with dual-slope characteristic described in Section 2.3.2:
STATOR DIFFER ENTIAL 87G on page 2–13. R efer to Figure 1–3: S IMPLE LOGIC DIAG RAM – 87G, 32 , 27 ,
59, AND AE on page 1–12 for the logic diagram of this function.
Function 87G will not operate for turn-to-turn faults in the machine windings.
It will also not operate for single-phase-to-ground faults if the system is ungrounded or high-impedance
grounded. Phase-to-ground protection by this function requires that the neutral of the machine (or another
machine operating i n parallel) be grounded. A small portio n of the windi ng next to th e neutral will no t be protected, the amount being determined by the voltage necessary to cause minimum pickup current to flow
through the neutral-to-g round impedance. Current-limiting devices in the neutral-ground c ircuit increase this
impedance and will decrease the ground-fault-protection coverage of this function.
1.3.3 CURRENT UNBALANCE (46T)
There are several cause s of generator unba lance . Som e of th ese i nclude unbala nced loads , unbal ance d sy s-
I
tem faults, and/or op en circuits. Th e negative-seque nce component (
) of stator current is directly r elated to
2
this unbalance and sets up a co unter-rota tin g flux fie ld in the mach ine . This in turn ca uses local he ating in the
rotor iron. The c apability of machines to withstand heating caused by unbalance current s is typically experessed in terms of an constant, and is supplied by the manufacturer of the machine.
The current unbalance tri p function (46T) of the DGP provides operating-tim e characteristics expressed as
2
I
T
= K, as shown in Fig ure 2 –6: TIME CURRENT CHARACTE RIS TIC O F 4 6T FUNC TI ON on pa ge 2–1 9. A
2
2
I
T
2
linear reset characteristic is incorporated to approximate the machine cooling following an intermittent currentunbalance condition. In addition to 46T, the DGP s ystem also includes a current-unba lance alarm function,
46A, which is operated by the nega tive-sequence component (I2) with an adj ustable pickup and time delay.
See Figure 1–4: SIMPLE LOGIC DIAGRAM – 46, 40, AND 51V on page 1–13 for the logic diagram.
1
1.3.4 LOSS OF EXCITATION (40)
This function is used to detect loss of excitation on synchronous machines. It includes two mho characteristics
looking into the machine, each with adjustable reach, offset, and time delay. Logic is provided to block this
function by presence of a negative-sequence voltage (indic ating a voltage trans former fuse failure VTFF condi tion) and/or an external VTFF Digital Input DI6 (see Figure 1–4: SIMPLE LOGIC DIAGRAM – 46, 40, AND 51V
on page 1–13).
Excitation can be los t due to ina dverten t trippi ng of the fi eld brea ker, open or short circui t on the fie ld wind ing,
regulator failure, or loss of the sour ce to the fie ld win ding. Loss of exci tation can b e dama ging to the m achin e
and/or detrimental to t he operation o f the sys tem. When a sy nchronous generator l oses exci tation, it will tend
to act as an induction generator: it will run above normal speed, operate at reduced power and receive its excitation (VARS) from the system. The impedance seen by a relay looking in to a generator will depend on the
machine characteristics, the load flow prior to the loss of excitation, and the type of excitation failure.
Studies indicates that first zone mho function (40-1) can be set to detect severe cases of excitation failure with
a shorter time d elay, whereas the second zone (40-2) c an be set to det ect all the excitation failure cases. A
longer time delay s etting is required for t he 4 0- 2 fu nc tio n fo r se cu ri ty duri ng sta ble power system swin g c ond itions. Figure 2–7: MHO CHARACTERISTICS FOR 40-1 & 40-2 FUNCTIONS on page 2–21 shows the characteristics of this function.
GE Power Management DGP Digital Generator Protection System 1-
7
Page 20
1.3 PROTECTION FEATURES 1 PRODUCT DESCRIPTION
1.3.5 ANTI-MOTORING (32)
1
On a total or partial loss of prime mover, if the power generated is less than no-load losses of the machine, real
power will start flowing into the generator. Typical motoring power of different kinds of prime movers are shown
in the table below. For a specific application, the minimum motoring power of the generator should be obtained
from the supplier of the unit.
The DGP system includes a reverse power function with adjustable time-delay. Either one or two (32-1 & 32-2)
independent setpoints are incorporated depending on the model number.
Table 1–4: TYPICAL MOTORING POWER
TYPE OF PRIME
MOVERS
Gas Turbine 10 to 100
Diesel 15 to 25
Hydraulic Turbine 2 to 100
Steam Turbine 0.5 to 4
The 32-1 can be configured as a part of sequential tripping logic as shown in Figure 1–3: SIMPLE LOGIC DIAGRAM – 87G, 32, 27, 59, AND AE on page 1–12. If the sequential trip logic is used, 32-1 is enabled when closing of turbine inlet v alves is indicated by digital in put DI2 following a turbine trip . The trip sequence is then
continued when timer TL1 times out. The 32-2, if included, is not dependent on the DI2 and is primarily
intended to provide bac k up t o th e s equ ent ial trip . If the sequential trip is no t en abl ed, the 32-1 can be used as
anti-motoring similar to 32-2.
A system must be protected against prolonged generator contribution to a fault. The DGP incorporates a timeovercurrent functio n with vo ltage re straint (51V ) to provi de part of the syst em backu p protecti on. As s hown in
Figure 1–4: SIMPLE LOGIC DIAGRAM – 46, 40, AND 51V on page 1–13, this function is supervised by a fault
detector and VTFF. The VTFF supervision can be by an internal an d/or external (DI6) VTFF fun ction. See Section 2.3.7: OVERCURRENT WITH VOLTAGE RESTRAINT (51V) on page 2–22 for the characteristic curves of
the 51V . Note that a separate algorithm is processed for each phase, with the restraint provided by corresponding phase voltage. The restraint is proportional to the magnitude of the voltage and is independent of the phase
angle. A linear reset characteristic is incorporated for this function.
MOTORING POWER IN %
OF UNIT RATING
1.3.6 TIME OVERCURRENT WITH VOLTAGE RESTRAINT 51V
1.3.7 ST ATOR GROUND (64G/27TN)
This function consists of two overlapping zones (64G1 and 64G2/27TN) to detect stator ground faults in a highimpedance-grounded generator system. The 64G1 is standard in all DGP models; however, the 64G2/27TN
function is provided in some models only. Together, the two zones cover 100% of the stator windings. See Figure 1–5: SIMPLE LOGIC DIAGRAM – 64G1, 64G2, 51GN, AND 24 on page 1–14.
Normally the generator-stato r neutral has a potential cl ose to ground. With the occurren ce of a stator ground
fault, a potential increase will occur on the neutral for all faults except those near the neutral. 64G1 uses a fundamental-frequency neutral overvoltage to cover about 95% of th e stator winding, depending on the pic kup
voltage setting. Alternately, 64G1 can be used as a generator-bus ground detector in a high-impedance
grounded or an ungrounded system. For this application, the VN input must be a zero-sequence voltage
derived from the generator bus, and functions 64G2/27TN must be disabled.
1-
8
DGP Digital Generator Protection System GE Power Management
Page 21
1 PRODUCT DESCRIPTION 1.3 PROTECTION FEATURES
64G2 is based on the perc entage of third-harmonic vo ltage at the generator neutral (VN 3) compared to the
total third-harmonic vol tage gener ated. This func tion is design ed to cover 15 % of the neutral end o f the stator
windings, and is supervised by fundamental and third-harmonic voltage thresholds. These thresholds are fixed
at 30 and 0.5 volts respectively. The third-harmonic comparator method eliminates the need to know the generator harmonic characteristic to use or set this function.
proper operation of 64G2
27TN is the third- harmonic neutral u ndervoltage functio n with a forward power supervision and can be used
with either wye or delta connected VTs. The percentage of stator windings covered by this function depends on
its threshold setting as well as the VN3 generated b y the machine at the time of th e fault. The magnitude of
VN3 under normal condi tions is a function of several factors, su ch as type of generator, load current, load
power factor, system status, etc. It can be very small (nearly zero) under some conditions. T o enhance security
during low VN3 vo lta ge conditions, this f unc tio n can b e i nhi bi ted by a se tt able window of forward power. However, it should be noted that other condi tions influenci ng the VN3 vol tage may make 2 7TN insecu re. In these
cases, function 64G 2 (available in some models; see the DGP nomenclature guide) or some other means
should be considered.
Digital input DI1 can be co nfigured to bloc k 64G2/27T N when the gener ator is off-line. Thi s provision is made
to enhance security of the functions under conditions such as static start of a gas turbine generator. Temporary
ungrounding of generator neutral during the static start can look like a ground fault near the neutral.
.
Note that wye-connected VTs are required for
1.3.8 GROUND OVERCURRENT (51GN)
1
51GN is an inverse overcurrent function available in some models. It can be used to detect stator ground faults
in a high or low resist ance grounded generator sy stem. See Fig ure 1–5: SIM PLE LOGIC DIA GRAM – 64G1,
64G2, 51GN, AND 24 on pa ge 1–14 for simplified logic diagram and Figure 2 –16: 51GN TIME-CURRENT
CHARACTERISTICS on page 2–39 for the inverse time-current characteristics.
This function uses current INR which can be derived by residual connection or by using a generator neutral CT
as noted in F igures 1–9: ELEMENTARY DIAGRAM WITH TE ST BLOCKS, WYE VTs and 1–12: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, DELTA VTs.
Since this function is independen t of the phase current inputs , it can alterna tely be connect ed to a CT in the
neutral of the generator step-up transformer.
1.3.9 OVEREXCITATION (24)
Overexcitation can b e caus ed by reg ulator failure , load r eject ion, or an exce ssiv e excit ation wh en the ge nerator is off-line. It can also resul t from decr easing spee d while the regulator o r an operator a ttempts to m aintain
rated stator voltage. The Volts/Hertz quantity is proportional to magnetic flux in the generator and step-up
transformer cores, and is use d to detect the overexcitation condition. Se e Figure 1–5: SIMPLE LOGIC DIAGRAM – 64G1, 64G2, 51GN, AND 24 for details.
The overexcitation protection includes trip (24T) and alarm (24A) functions. 24T consists of an inverse function
and an instantaneous fu nction with time-delay characteris tics. The combination of these two char acteristics
allows the 24T setting to cl osely follow the generator and/or ste p-up transformer V/Hz limit curve. Bo th 24A
and 24T are computed for each of the three phase voltages (see Table 2–3: 24A VOLTAGES on page 2–30).
Function 24T can be c onfigu red to operate d ifferent ou tput re lays for gene rator on -lin e and o ff-line condi tions.
This function incorpora tes a user-settable li near reset character istic to mimic machi ne cooling. The figu res in
Section 2.3.12: OVEREXCITATION TRIP (VOLTS/HERTZ: 24T) show the characteristics of this function.
GE Power Management DGP Digital Generator Protection System 1-
9
Page 22
1.3 PROTECTION FEATURES 1 PRODUCT DESCRIPTION
1.3.10 OVERVOLTAGE (59)
1
This function consists of a positive-sequence overvoltage with an user selectable inverse or definite time characteristic. See Figure 1–3: S IMPLE LOGIC DIAGRAM – 87G, 32, 27, 59, AND AE on page 1–12 fo r the logic
diagram and Figure 2–15: 59 TIME-VOLTAGE CHARACTERISTICS on page 2–35 for the inverse time-voltage
characteristics. A l inear reset charact eristic is incorp orated for this function. The overvoltage functi on can be
considered as a backup to the Volts/Hz function. Some possible causes of this cond ition are a system dis turbance or regulator failure.
1.3.11 UNDERVOLTAGE (27)
This function consists of a positive-sequence undervoltage with an user selectable inverse or definite time
characteristic. See Figur e 1–3: SIMPLE LOGIC DIAG RAM – 87G, 32, 27, 59, AND AE on p age 1–12 for the
logic diagram and Figu re 2–17: 27 TIME -VOLTAGE CHARACTER ISTICS on pa ge 2–40 for the inv erse timevoltage characteristics. A linear reset characteristic is incorporated for this function.
1.3.12 OVER AND UNDERFREQUENCY (81)
This function provides over and underfrequency protection, each with an adj ustable time delay. Two or four
over and underfrequency ste ps are provided dep ending on the model. Al l frequency functi ons are supervise d
by an adjustable positive-sequence voltage level. This undervoltage cut-off level and/or digital input DI1 can be
used to block the freq uency functions during sta rt-up. Fr equency dis turbance c an occur due to a system fault
or islanding of the unit or an unconnected unit can operate at abnormal frequency due to malfunction of speed
control. Figure 1 –6: SIMPLE LOGIC DIA GRAM – 81-O A ND 81-U on page 1 –15 show s the l ogic diag ram for
this function.
1.3.13 VOLTAGE TRANSFORMER FUSE FAILURE (VTFF)
Functions 40 and 51V may operate for a full or partial loss of AC potential caused by one or more blown fuses.
The DGP makes provisions to block tripping by these functions when a fuse failure is detected; all other protection functions are a llowe d to t rip. Fig ure 1–7: SIMP LE L OGIC DIA GRAM – VT F USE FAILURE on pag e 1–1 6
shows the logic diagram for the VTFF function.
If AC potential is lost on one or more phas es, the negative-seque nce voltage (V2) rise s and/or the positivesequence voltage ( V1) drops. Either V2 > 15V or V1 < 50V provides a basic ind ication o f the VTFF c ondition .
This signal is supervi sed by a Distur bance Dete ctor (DD) and gene rator posit ive-se quence cu rrent (I1) dete ctor (see three-inp ut AND gate on the log ic diagram). Supervision by the DD and I1 signa ls provide security
against false ope ration du ring fault a nd genera tor out of service conditio ns respec tively. Security is enhance d
by use of the A/0 and B/0 timers shown in the logic diagram.
Signal DD is derived from a combination of sequence current levels, change in levels, and pickup flags of various protection functions as shown in the logic diagram.
The VTFF logic allows integration of an external VTFF contact. Either of the two fuse-failure signals or both
signals can be configured to block tripping of functions 40 and 51V.
Detection of VTFF energizes the 74FF (Fuse Failure alarm) relay, de-energizes the 74CR (critical alarm) relay,
and turns the status LED red, even though all protection functions except 40 and 51V are unaffected.
1-
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DGP Digital Generator Protection System GE Power Management
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1 PRODUCT DESCRIPTION 1.3 PROTECTION FEATURES
1.3.14 ACCIDENTAL ENERGIZATION (AE)
The DGP includes logic to detect accidental energization of the gener ator (see Figure 1–3: SIMPLE LOGIC
DIAGRAM – 87G, 3 2, 27, 59, AND AE on page 1–12). When a generator is energized while at standstill or
reduced speed, it behaves and acc elerates as an induction mot or. The machine terminal voltage and current
during such an event will be a function of generator, transformer, and system impedances.
An instantaneous over cu rren t si gna l (50) is used to det ect t he acci de ntal ener g izati on. T his s ig nal is arm ed by
a logic signal de rived from positive- sequence voltage and GEN O FF LINE input DI1. These two "arming " signals can be confi gured in AND or O R mode by Se tting 2703:
after the generator is taken out of service. The logic automatically disarms itself during a normal start-up
sequence when the voltage detector picks up and/or the generator is on-line.
For the AE logic to perform, special precautions must be taken to ensure that the DGP system and associated
trip circuits remain in service when the generator is out of service. Additionally, the generator off-line input, DI1,
must be reliable. It should also be noted that the pickup flag of function 51V is used as signal 50; therefore this
logic will automatically be disabled if function 51V is disabled.
AE ARM
. The 50 function is armed 5 seconds
1
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1
1.3 PROTECTION FEATURES 1 PRODUCT DESCRIPTION
Stator
Differential
50 (51V Pickup Flag)
VTFF
V1 < 30V
DI1
(+)
Gen. Off-line
OR
AE ARM
Reverse Pwr.
No. 1
(+)
DI2
Turbine Inlet Valve
Closed
Seq. Trip Enabled
DI1
(+)
Gen.
Off-Line
SELBKDI1
Reverse Pwr.
No. 2 (1)
AND
AND
AND
AND
PU
OR
PU=5 sec
DO=0.25 sec
DO
ANDOR
AND
AND
AND
TL1
TL2
87G
87G
AE
AE
32-1
32-2
OR
OR
OR
OR
OR
OR
TRIP A
94G
TRIP B
94G1
TRIP C
94G2
TRIP D
94G3
ALARM
74A
ALARM
74B
Overvoltage
59
Undervoltage
(+)
(1)
DI1
Gen.
Off-Line
AND
27
NOTES:
(1) Indicates an optional function (includes associated logic). Refer to
CONFIGURABLE
DGP nomenclature selection guide for available functions in a
specific model.
(2) Each of the available protection functions can be configured to
operate any combination of the 8 output relays (4-Trip and 4-Alarm).
Figure 1–3: SIMPLE LOGIC DIAGRAM – 87G, 32, 27, 59, AND AE
LOGIC (2)
OR
OR
ALARM
74C
ALARM
74D
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DGP Digital Generator Protection System GE Power Management
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1 PRODUCT DESCRIPTION 1.3 PROTECTION FEATURES
1
Overcurrent
(voltage restraint)
VTFF + DI6
FD
(+)
(+)
DI3
External Trip - 1
DI4
External Trip - 2
Current Unbalance
(Alarm)
Current Unbalance
(Trip)
Loss of Excitation
Zone 1
Loss of Excitation
Zone 2
DI6
(+)
V
2
Ext. VTFF
>
PU
15V
PU=3 Samples
DO=5 Samples
DO
ENA
SELV2SUP
DIS
OR
AND
TL21
(1)
TL22
(1)
TL14
87G
51V
OR
TRIP A
94G
AE
TRIP B
94G1
TRIP C
94G2
TRIP D
94G3
DI3
DI4
46A
OR
OR
OR
46T
TL12AND
TL13AND
40-1
40-2
OR
OR
OR
ALARM
74A
ALARM
74B
ALARM
74C
OR
ALARM
74D
NOTE:
(1) Timers TL21 and TL22 are available in models DGP***ACA only.
(2) Each of the available protection functions can be configured to
operate any combination of the 8 output relays (4-Trip and 4-Alarm).
CONFIGURABLE
LOGIC (2)
DSPLGC2.VSD
Figure 1–4: SIMPLE LOGIC DIAGRAM – 46, 40, AND 51V
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1
1.3 PROTECTION FEATURES 1 PRODUCT DESCRIPTION
Stator Ground
Zone 1
Stator Ground
Zone 2 (1)
VP3 > 0.5V
V1
30V
>
DI1
(+)
Gen.
Off-Line
V
≤
N3
GEN. OFF-LINE
(+)
DI1
V
25V
≥
1
SELBKDI1
27TN PICKUP
SELBKDI1
POWER < FORPWR-L
POWER > FORPWR-H
Neutral Overcurrent
(1)
OR
AND
TL4
TL5
AND
TL20
64G1
64G2
27TN
(1)
51GN
OR
OR
OR
OR
OR
OR
TRIP A
94G
TRIP B
94G1
TRIP C
94G2
TRIP D
94G3
ALARM
74A
ALARM
74B
Overexcitation
(Alarm)
Overexcitation
(Trip)
Time
Inst
TL7
TL6
OR
(+)
DI1
Gen.
Off-Line
AND
AND
24A
24T
(On-Line)
24T
(Off-Line)
NOTES:
(1) Indicates an optinal function (includes associated logic). Refer to
DGP nomenclature selection guide for available functions in a
specific model.
CONFIGURABLE
(2) Each of the available protection functions can be configured to
operate any combination of the 8 output relays (4-Trip and 4-Alarm).
Figure 1–5: SIMPLE LOGIC DIAGRAM – 64G1, 64G2, 51GN, AND 24
LOGIC (2)
OR
OR
ALARM
74C
ALARM
74D
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1 PRODUCT DESCRIPTION 1.3 PROTECTION FEATURES
1
Under Frequency
Set Point - 1
Under Frequency
Set Point - 2
Under Frequency
Set Point - 3 (1)
Under Frequency
Set Point - 4 (1)
DI1
(+)
Gen.
Off-Line
SELBKDI1
V1 > UVCUTOFF
Over Frequency
Set Point - 1
AND
AND
AND
AND
AND
TL8
TL9
TL10
TL11
TL15
81-1U
AE
81-2U
81-3U
81-4U
81-1O
OR
OR
OR
OR
OR
OR
TRIP A
94G
TRIP B
94G1
TRIP C
94G2
TRIP D
94G3
ALARM
74A
ALARM
74B
Over Frequency
Set Point - 2
AND
TL16
81-2O
Over Frequency
Set Point - 3 (1)
AND
TL17
81-3O
Over Frequency
Set Point - 4 (1)
AND
TL18
81-4O
NOTES:
(1) Indicates an optional function (includes associated logic). Refer to
DGP nomenclature selection guide for available functions in a
specific model.
(2) Each of the available protection functions can be configured to
operate any combination of the 8 output relays (4-Trip and 4-Alarm).
CONFIGURABLE
Figure 1–6: SIMPLE LOGIC DIAGRAM – 81-O AND 81-U
OR
OR
LOGIC (2)
ALARM
74C
ALARM
74D
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1
1.3 PROTECTION FEATURES 1 PRODUCT DESCRIPTION
DI6
(+)
External VTFF
V2
15V
>
50V
V1
<
51V Pickup Flag
40 Pickup Flag
87G Pickup Flag
51GN Pickup Flag
21 Pickup Flag (Fut.)
I0 ≥ 0.6 / *
∆
∆
I2 ≥ 0.6 / *
∆
I0| ≥ 0.2 / *
|
I1| ≥ 0.2 / *
|
∆
|∆I2| ≥ 0.2 / *
64G1 Pickup Flag
64G2 Pickup Flag
DI1
(+)
Gen.
Off-Line
PU
PU=9000 samples
DO=0
SELBKDI1
DO
OR
I1 > 0.1/*
OR
OR OR
OR
AND
AND
AND
PU
DO
PU = 36 samples
DO = 0
FD
OR
Supervise
51V,
21(Future)
OR
DD
ENA
DIS
VTFF
VTFF + DI6
OR
Supervise
51V,
21(Future)
VTFF Alarm
Critical Alarm
1-
NOTE:
* = 1 FOR 5 AMP RATED DGPs.
* = 5 FOR 1 AMP RATED DGPs.
Figure 1–7: SIMPLE LOGIC DIAGRAM – VT FUSE FAILURE
16
DGP_VTFF.VSD
DGP Digital Generator Protection System GE Power Management
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1 PRODUCT DESCRIPTION 1.4 OTHER FEATURES
1.4 OTHER FEATURES 1.4.1 INPUTS
The DGP system takes eight current and four voltage inputs (refer to Section 1.5: ELEMENTARY DIAGRAMS).
The input currents in terminals BH1, BH3, and BH5 (I
, IBS, and ICS) are used to process functions 46, 40, 32,
AS
and 51V. As noted in the elementary diagrams, these currents can be derived from system side or neutral side
CTs as de sired. Either the sy stem or n eutral s ide CTs can be used fo r these functi ons if the Stator D ifferential
(87G) function is enabled.
The current input s I
and INR are derived from th e resid ual connec tions of t he respe ctive phas e CTs and do
NS
not require dedicated neutral CTs. Zero-sequence current at system and/or neutral side of the generator stator
windings is calculated and then compared with the measured I
and/or INR values by the DGP as a part of the
NS
background self-test.
The I
icated neutral CT can be used for the input I
The DGP phase volta ge i npu ts c an be wye or delta and are derived f ro m the gen er ato r term in al v ol tag e. V
current is used to process the 51GN function (not available on DGP***AAA models). If desired, a ded-
NR
NR
.
is
N
derived from the generator neutral grounding transformer.
A time synchronizin g signal can be connected to the DGP for syn chronization to within 1 ms of a referenc e
clock. Either IRIG-B or GE's G-NET system signal can be used. This signal is required only if it is necessary to
synchronize the DGP to an external reference clock.
Six digital inputs can be connected to the DGP. Two of these inputs (DI3 and DI4) are a ssigned for possi ble
routing of external trip/alarm signals to take advantage of the output configuration or sequence-of-events capability. Generator off-line (DI1), turbine inlet-valve-close indication (DI2), and external VTFF (DI6) inputs are
used for various relay logic functions. A contact input, (DI5), can also be used to trigger the optional oscillography feature. In some models, the DI6 input can be configured as external VTFF or DISABLE ALL PROTECTION (refer to Section 1.5: ELEMENTARY DIAGRAMS for details).
1
The digital input circuits are universally rated for nominal control voltages of 48 to 250 V DC.
1.4.2 OUTPUT RELAYS
The DGP system includes ei ght user-configur able output relays. Four of these relays (94G, 94G1, 94G2 and
94G3) are high speed (4 ms) trip-duty rated with two form A contacts each. The remaining four (74A, 74B, 74C
and 74D) are standard speed (8 ms) with one form C contact each, intended for alarms. Each of the protection
functions can be configured to operate any number of these output relays. The trip outputs are intended for, but
not limited to, the following purposes:
• 94G: trip a lockout relay to shut down the machine
• 94G1: trip field breaker
• 94G2: trip main generator breaker or breakers
• 94G3: operate a lockout relay to trip turbine.
In addition to the configu rable output relays, fi ve pre-defined alarm duty relays with one form C c ontact each
are included. These alar m relays inc lude critical and non-cri tical self- test alarms ( 74CR and 74NC) , the VTFF
alarm (74FF), and loss of power-supply alarms (PS1 and PS2). The form C contact of each of the alarm relays,
except PS1 and PS2, are wired out to the terminal block. A hard wire jumper is used to select either the form A
or the form B conta ct of each of the PS1 and P S2 relays, as shown in Figure 3–3: DGP POWER S UPPLY
MODULE on page 3–4.
All alarm relays, wi th the exc eption of 74CR, PS1 a nd PS2, are e nergized wh en the appr opriate al arm conditions exist. Relays 74CR, PS1 and PS2, however, are energized under no rmal conditions and will dro p out
when the alarm conditions exist.
GE Power Management DGP Digital Generator Protection System 1-
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1.4 OTHER FEATURES 1 PRODUCT DESCRIPTION
Also included are two additional relays (TEST PICKUP and TEST TRIP) that can be configured to operate by a
selected protectio n function pi ckup flag an d trip output. T hese two outpu ts are inten ded to facilitate testing of
1
the selected protection function.
A Contact Expansi on Unit is al so av ailable whic h can be u sed with DGP* **ACA models . The Gene ral El ectric
DEC1000 Contact Expa nsion Unit provides eleven a dditional output relays that can be factory config ured to
user specifications. Refer to the GE Power Mana gement Product Ca talog, the GE Pow er Management Products CD, or instruction book GEK-105561 for additional details on the DEC1000.
1.4.3 START-UP SELF-TESTS
The most comprehens ive testing of the DGP is perform ed during powe r-up. Since the DG P is not perform ing
any protection activities at that time, tests (such as RA M tests) that would norm ally be disruptive to ru n-time
processing are per formed during the start-up. Al l processors p articipate in th e start-up sel f-test process. T he
processors commun ic ate th eir results to each other so that any failures foun d c an be r epo rt ed to t he us er an d
to ensure each processor successfully completes its assigned self-tests before the DGP system begins protection activity.
During power-up, the micr oprocessors perfor m start-up self-test s on their associated ha rdware (PROM, local
RAM, shared RAM, interrup t controller, timer chip, serial and parallel I/O ports, non-volatile memory, analog
and digital I/O circuitry, MMI hardware, etc.). In addition, the DGP system verifies that the PROM version numbers in all processor boards are compatible. The components tested at start-up are listed in Table 6–1: ST ARTUP SELF-TESTS on page 6–2.
In most cases, if any critical self-test failure is detected, the DGP will not continue its start-up but will not cause
a reset. An attempt will be made to store the sy stem status, to initi alize the MMI and remote communications
hardware/software for communication status, and to print a diagnostic message. The critical alarm relay will be
de-energized.
If no failures are detected, the DGP completes initialization of its hardware and software. Next, each processor
board (DAP and S SP) will enable the outputs. As a f inal step, the DG P checks the res ults of all the te sts to
determine whether to turn the front panel status LED to green.
The start-up procedure takes approximately one minute. As soon as the SSP successfully completes its
PROM test and in itializ es the disp lay h ardwa re, th e mes sage
system initialization is completed, the display is blanked and the relay begins acquiring and processing data.
Each of the processors has "idle time" when the system is in a quies cent state; that is, when the DGP is not
performing fault or po st-fa ult proc essi ng. During this i dle tim e, each proce ssor pe rforms backg round self-tes ts
that are non-disruptive to the foreground proc essing. If any back ground self-tes t fails, the test is repeat ed. To
declare a component FAILED , the test must fail three consec utive times. In the case of criti cal failures, the
DGP forces a self reset to resume operation again after an intermittent failure. The reset activities are identical
to the start-up activities except that not all start-up self-tests are performed.
A reset is not reported to the user by the DGP system. If the reset is successful, no message is printed, no failure status is recorded, an d the critical alarm is not generated. However, during the reset proc edure, the red
LED on the MMI panel will light and a failure code ma y appear on the MM I displa y. If the reset is not successful, the processor boar d will be shut down, leaving the MMI panel displaying the error information. Ref er to
Section 6.4: ERROR CO DES on page 6–7 fo r error codes. To prevent continual resets in the ca se of a solid
failure, both hardware and software will permit only four resets in a one hour period. On the fifth reset, the DGP
will not perform initialization, but will attempt to initialize MMI, communications, and the critical alarm output, as
in the case of a start-up with a critical self-test failure.
INITIALIZING
will be displayed. When the DGP
1.4.4 RUN-TIME SELF-TESTS
1-
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DGP Digital Generator Protection System GE Power Management
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1 PRODUCT DESCRIPTION 1.4 OTHER FEATURES
The components tested in the backg round are listed in Table 6–2: RUN-TIME BACKGROUND SELF-TESTS
on page 6–3. The testing of I/O hardware is done in the foreground so the processors know when a given component or port is in u se and therefore n ot available f or testing. The com ponents tested in the foreground are
listed in Table 6 –3: RUN-TIME FOREGROUND SELF-TESTS on p age 6–3. Some foreground tests are performed every sample period while others are performed less frequently. As with background self-tests, any
failed test is repeated and must fail three consecutive times to be considered a failure. Although not specifically
a self-test, trip circuit c onti nui ty mo nit or ing is a lso p er forme d a s a foreg ro und tes t. Refe r to th e T RIP CIR CUIT
MONITOR section below.
In addition to backgroun d self-tests, the operato r may initiate a vi sual-response test of the MMI components.
Refer to Section 4.6.2 T1: MMI STATUS AND DISPLAY TESTING on page 4–9 for details.
1.4.5 ADAPTIVE SAMPLING FREQUENCY
The DGP system samples analog input waveforms at a rate of 12 samples per cycle. An adaptive sampling frequency is used to m aintain th is rate ov er the power system fr equencies of 30.5 to 7 9.5 Hz. As a resu lt of this
feature, the measurem ent accuracy of the analog inp uts and the sensitivities of t he protection functions ar e
maintained over the ran ge of power system frequenci es. This feature provid es improved protection for fau lts
during off-normal frequenci es (such as start-up conditions). Figure 1–8: FREQUENCY-SENS ITIVITY CHARACTERISTICS shows variations in sensitivity of protection functions at different power system frequencies.
The sampling frequency is bas ed on 30.5 Hz for powe r system frequencies below 30.5 Hz and 79.5 Hz for the
frequencies above 79.5 Hz. In eit her case, i f the AC v oltage to the DGP drops below approx imately 20 V, the
sampling freque ncy is automati cally reca lculated on the basis of the nominal system frequency (S etting 102:
SYSFREQ
).
1
The sampling fr equency, which is 12 times the meas ured system freque ncy, can be accessed as one of the
Present Values.
1.4.6 TRIP CIRCUIT MONITOR
The trip circuit m onitor c onsis ts of D C vol tage an d curr ent mon itors ( TVM a nd TC M respe ctiv ely). E ach o f the
trip contacts shown with polarity marks in the elementary diagrams (see Section 1.5: ELEMENTARY DIAGRAMS) is monitored. TVM and TCM can be selectively disabled for each of the trip circuits.
Under normal conditions, DC vo ltage ac ross each of the contac ts is conti nuous ly monitored . If the DC voltag e
becomes virtually zero, then the trip circuit has "failed open". The TVM is active only when the generator is online, as indicated by th e i nput DI1. Th is function is intended to r ep lac e t he i ndi ca tin g l igh t typi ca ll y u se d for tri p
circuit monitoring. It is universally r ated for 48 through 2 50 V DC. A non-crit ical alarm is ge nerated when the
TVM detects an abnormality.
When the DGP system issues a trip, DC current through each of the appropriate trip contacts is monitored. The
trip relay is sealed -in, a s l ong as the cur r ent is flo win g, to pr ote ct th e contact. A minimum current o f 15 0 mA is
required for the TCM to recognize the trip current. Status of the trip current flow following issuance of any trip is
logged in the sequence of events.
1.4.7 SEQUENCE OF EVENTS
This function time -tags an d stor es the l ast 1 00 ev ents in m emory. The resolution of th e time -tagging is 1 mill isecond. The event list conta ins power sy stem events , opera tor actions, and se lf-te st alarms . The sequenc e of
events can be accessed, either locally or remotely, by a PC via one of the RS232 ports. A full description of this
function is contained in the Chapter 8: INTERFACE.
GE Power Management DGP Digital Generator Protection System 1-
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1.4 OTHER FEATURES 1 PRODUCT DESCRIPTION
1
12
11
10
9
8
7
6
Relative Sensitivity
5
4
Frequency Vs Sensitivity
DGP Relay System
64G1
32
24
3
46
2
1
0
59
51V
87G
0 102030405060708090100
System Frequency
32
46
24
Figure 1–8: FREQUENCY-SENSITIVITY CHARACTERISTICS
1.4.8 TIME SYNCHRONIZATION
The DGP system includes a real time clock that can run freely or be synchronized from an external signal. Two
different external time-sync signals are possible. If the DGP is connected to the host computer of a G-NET substation information and contr o l s yste m, then th e DG P rec ei ves a ti me-s yn c puls e v ia pi n 2 5 o f p or t P L-1. If the
DGP is not connected to a G-NET host computer, then a demodulated IRIG-B signal connected to optional port
PL-3 may be used to sy nchroni ze the clock. In bo th cases , the cl ock i n a given DG P is synch ronized to withi n
±1 mill is ec o nd of any o t he r di g it a l re lay cl ock, provided the two relays a re wi re d t o th e sa m e sy nc hr on iz in g s ig nal.
1-
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1 PRODUCT DESCRIPTION 1.4 OTHER FEATURES
1.4.9 FAULT REPORT & OSCILLOGRAPHY DATA
A fault report is initiated by any one of the protection-function pickup flags or an optional external oscillography
trigger input, DI5. For the fault report to be completed and stored, the DGP either has to issue a trip or the DI5
input contact must close any tim e during the fault report period. The fau lt report period begins when the firs t
protection function fla g is up or the DI5 in put co ntact is c losed. It end s when the DGP is sues a trip or when i t
has captured the selected number of post-fault waveform cycles, whichever is later. If all the pickup flags reset
without issuing a trip and the DI5 does not close, the fault report initiated by the protection flag will not be completed or stored.
The fault report includes the Unit ID, date and time, system operating time, pre-fault metering values, fault currents and voltages, trip/fa ult types, and up to 14 s equence-of-even t points logged after init iation. The system
operating time (OP TIME) is the time difference between the first prote ction function pickup flag and the first
protection function tri p. The DG P st ores the last three f ault repo rts i n its memory. A full description of the fault
report is contained in Chapter 8: INTERFACE.
DGP models with oscillography data capture capability will store waveform data in their memory each time the
system stores a fault report. A total of 120 cycles of data can be stored. The 120 cycles in memory are divided
in one, two, or three pa rtitions , bas ed on Setti ng 111:
fault can be set up to 20 cycles. It should be noted that the pre-fault cycles are based on the first flag or DI5 to
initiate the data capture.
Oscillography data in cludes station and generator identificat ion, a complete list of settings, the fault report,
internal flags, and a se lected number of pre-fault and post-fault wavef orm cycles. This data can be displa yed
using the GE-Link software program. See Chapter 10: GE-LINK SOFTWARE for details.
NUM FLTS
. The number of prefa ult cyc les cap tured per
1.4.10 LOCAL MAN-MACHINE INTERFACE
1
A local man-machine inte rf ace (M MI) , inc or porati ng a key pa d, LE D di splay, and 19 target LEDs, is pro vided to
allow the user to enter settin gs, display pres ent values, view fault ta rget informati on, and access sto red data.
The use and functioning of the MMI is fully described in the Chapter 8: INTERFACE.
1.4.11 LOCAL PRINTER
An optional printer port (PL- 2) on the rear of th e DGP permits the us e of a serial printe r. The port can also be
used to connect the DEC1000 Contact Expansion Unit (DGP***ACA models only) which provides eleven additional output relay s. The sequence-of-even ts (SOE) data are avai lable at this port for immediate printing as
they occur. Additionally, for DGP***AAA models, a variety of inform ation stored in the DGP system memo ry
can be printed when requested via the local MMI; see Chapter 8: INTERFACE for details.
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1.4 OTHER FEATURES 1 PRODUCT DESCRIPTION
1.4.12 REMOTE COMMUNICATIONS
1
Two RS232 serial ports permit the u ser to communicate with the DGP from a n IBM PC- compatibl e compute r.
One of the ports, a DB-25 (PL-1), is located on th e rear of the case an d the othe r, a DB-9 (COMM), is located
on the front plate of the MMI module.
A PC may be connecte d to the DGP with a proper null-modem cable, provided the cable length does not
exceed 50 feet. The PC can also be connected via interposing modems if it is physically remote from the DGP.
GE-Link software is required to communicate with the DGP. The capabilities and use of the software are
described in Chapter 10: GE-LINK SOFTWARE. Refer to Chapter 9: COMMUNICATIONS for details regarding
the required cables and proper connection.
When a connection to the ho st computer of a stati on integratio n system is desi red, the following two ph ysical
connectio ns are possible:
• Standard hard-wire cables may be used for distances up to 50 feet.
• For longer distances it is possible to add an optional external adapter that plugs into PL-1 to provide a fiber
optic link between the DGP and the host computer. An isolated 5 V DC supply is internally connected to pin
11 of PL-1 to power this external adapter.
Cables and associate d equipment can be connected to each port si multaneousl y. However, when one port is
active the other is effectively disabled. For instance, when PL-1 is connected to host computer of an integration
system, it is not possible to log into the DGP from the front port when the integration system is active. If PL-1 is
connected to a modem and the front port is connected to a PC usi ng a null-modem cable, then th e first port
that becomes active is given preference, and the other port is disabled until the first is released.
1.4.13 REMOTE CONTROL
By using the local MMI or a remote PC connected to the RS232 port, it is possible to selectively operate any of
the four trip output relays fo r remote control. The control actio n may include shutdown of the mac hine, field
breaker trip, main g enerator brea ker trip, turbine trip, etc., depending on the equ ipment c onnected to the outputs. The controls descr ibed above are enabled or disabled by a ha rd-wired ju mper loca ted on the MMI module (see Figure 3–4: DGP MMI MODUL E on page 3– 5). As shi pped from the f actory, this jumper is physic ally
present and the Remote Control is disabled. To enable Remote Control, the jumper must be removed.
1.4.14 PASSWORD PROTECTION
Passwords provide sec urity when using the lo cal int erface (MMI) or duri ng remote commun ication s while running the GE-Link program. Two different passwords provide local MMI security for:
1. control operations (close trip-output contacts)
2. settings changes.
Three different passwords in the GE-Link program provide remote communications security for:
1. view and upload information
2. control operations
3. settings changes
Refer to the Chapter 8: INTERFACE for a descripti on of MMI password usag e, and refer to Chapter 10 : GELINK SOFTWARE for a description of GE-Link password usage.
1.4.15 REMOTE COMMUNICATIONS – MODBUS PROTOCOL
The RS232 serial ports can be used with an optional RS485 to RS232 converter. Refer to Chapter 9: COMMUNICATIONS for further information on Modbus communication.
1-
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DGP Digital Generator Protection System GE Power Management
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1 PRODUCT DESCRIPTION 1.5 ELEMENTARY DIAGRAMS
1.5 ELEMENTARY DIAGRAMS
1
Figure 1–9: ELEMENTARY DIAGRAM WITH TEST BLOCKS, WYE VTs
GE Power Management DGP Digital Generator Protection System 1-
23
Page 36
1
1.5 ELEMENTARY DIAGRAMS 1 PRODUCT DESCRIPTION
1-
24
Figure 1–10: ELEMENTARY DIAGRAM WITH TEST BLOCKS, DELTA VTs
DGP Digital Generator Protection System GE Power Management
Page 37
1 PRODUCT DESCRIPTION 1.5 ELEMENTARY DIAGRAMS
1
Figure 1–11: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, WYE VTs
GE Power Management DGP Digital Generator Protection System 1-
25
Page 38
1
1.5 ELEMENTARY DIAGRAMS 1 PRODUCT DESCRIPTION
1-
26
Figure 1–12: ELEMENTARY DIAGRAM WITHOUT TEST BLOCKS, DELTA VTs
DGP Digital Generator Protection System GE Power Management
Page 39
1 PRODUCT DESCRIPTION 1.5 ELEMENTARY DIAGRAMS
1
0286A2925ASH1.DWG
0286A4911 SH9.DWG
Figure 1–13: DIGITAL RELAY SYMBOL LEGEND
GE Power Management DGP Digital Generator Protection System 1-
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Page 40
1
1.5 ELEMENTARY DIAGRAMS 1 PRODUCT DESCRIPTION
1-
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DGP Digital Generator Protection System GE Power Management
Page 41
2 CALCULATION OF SETTINGS 2.1 GENERAL
2 CALCULATION OF SETTINGS 2.1 GENERAL 2.1.1 DESCRIPTION
This section provides information to assist the user in determining settings for the DGP™ generator protection
system. Some settings are determined by the size and type of generator and the system to which it is connected, while other settin gs are the sa me r ega rdle ss of the machine and/or system. O ther se tti ngs may be se t
according to user preference.
Settings that are i ndependent of system and machine size/type will be pr esented first, followed by machine
and system-dependent settings. A blank setting form is provided (see Table 2–5: DGP***AAA SETTINGS
TA BLE on page 2–41) and may be used to record model number, PROM version number, and settings for specific applications.
Table 2–1: DGP SYSTEM SETTINGS & RATINGS on page 2–3 lists all the settings and the corresponding
ranges and units. T he column labeled D EFAULT indicates th e DGP system setting s stored in memory when
shipped from the fac tory. The settings described in the s ubsequent se ctions are ar ranged by categ ory, corresponding to the category headings on the light-emitting diode (LED) display of the local man-machine interface
(MMI). Individual s etti ngs a nd ca tego ry h ead ings are listed by the des c ripti ve na me followed by its mne mon ic .
The DGP displays the mnemonic to identify a particular setting or category-of-setting heading.
In the following secti on, a set of example settings bas ed on a typical generator sy stem is presented. By no
means does this presentation encompass all possible setting scenarios or calculations. It is provided as a
demonstration for the setting methods and procedures to follow.
A sample generator system diagr am is show n on the follow ing pa ge; it w ill be us ed to d emons trate the example settings for a typical DGP protection system.
2
GE Power Management DGP Digital Generator Protection System 2-
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Page 42
2
2.1 GENERAL 2 CALCULATION OF SETTINGS
Power System
52G
GSU Transformer
200 MVA
18 : 138 KV
8000:5 A
G
X1 = 10%
18900:120 V
Generator
211,765 KVA, 18KV
X'd = 0.216 PU
Xd = 1.967 PU
2
I
T capability = 10
2
capability = 8%
I
2
Motoring power = 22000 KW
DGP Protection System
94G
VA, VB, VC
94G1
IAS, IBS, ICS, INS
94G2
94G3
Configurable
Outputs
To
Trip
Circuits
8000:5 A
12000:240V
IAR, IBR, ICR, INR
VN
1.45 Ohm
Figure 2–1: SAMPLE GENERATOR SYSTEM
74A
74B
74C
74D
SAMPGEN.VSD
To
Alarm
Circuits
2-
2
DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.1 GENERAL
T able 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 1 of 7)
SETTING
NUMBER
CONFIGURATION: CONFIG
101 UNITID 0 to 9999 (GEmodem protocol)
102 SYSFREQ 50 / 60 Hz 60
103 SEL TVM 0000 to 1111 N/A 0000
104 SEL TCM 0000 to 1111 N/A 0000
105 SELPRIM PRIMARY (0); SECNDRY (1) N/A SECNDRY
106 CT RATIO 1 to 50000 N/A 1
107 VT RATIO 1.0 to 240.0 N/A 1.0
108 COMMPORT Format:
109
c
110 TIMESYNC INTRNL (0); IRIG-B (1)d; G-NET (2) N/A INTRNL
111 NUM FLTS 1 to 3 N/A 3
MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
N/A 0 (GEmodem)
1 to 127 (Modbus protocol)
xxyz
, where
Baud Rate (
Parity (
PHASE A-B-C (0); A-C-B (1) NA A-B-C
xx
): 03, 12, 24, 48, 96 (× 100)
y
): 0 (None), 1 (Odd), 2 (Even)
Stop Bits (
z
): 1, 2
N/A 2401
1 (Modbus)
2
112
d
113
d
114 NOM VOLT 100.0 to 225.0 de / 100.0 to 140.0
115 RATEDCUR 0.10 to 9.99 0.02 to 1.99 A 5.00 1.00
116 VT CONN WYE (0); DELTA (1) N/A WYE
117
e
STATOR DIFFERENTIAL: 87G
201 TRIP 0000 to 1111 N/A 0000
202 ALARM 0000 to 1111 N/A 0000
203 K1 1.0 to 10.0 % 5.0
204 PICKUP 0.20 to 1.00 0.04 to 2.00 A 0.30 0.06
CURRENT UNBALANCE – ALARM: 46A
301 ALARM 0000 to 1111 N/A 0000
302 PICKUP 0.05 to 2.99 0.01 to 0.60 A 0.05 0.01
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PREFLT 1 to 20 cycles 20
OSC TRIG DI ENA (0); DI DIS (1) N/A DI ENA
f
NCTRATIO 1 to 50000 N/A 1
.
V 120.0
GE Power Management DGP Digital Generator Protection System 2-
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2.1 GENERAL 2 CALCULATION OF SETTINGS
Table 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 2 of 7)
2
SETTING
NUMBER
303 TL14 1 to 9 sec. 1
CURRENT UNBALANCE – TRIP: 46T
401 TRIP 0000 to 1111 N/A 0000
402 ALARM 0000 to 1111 N/A 0000
403 PICKUP 0.05 to 2.99 0.01 to 0.60 A 2.00 0.40
404 K2 1.0 to 45.0 sec. 1.0
LOSS OF EXCITATION – SUPERVISION: 40
501 SELV2SUP DISABLE (0); ENABLE (1) N/A DISABLE
LOSS OF EXCITATION – ZONE 1: 40-1
601 TRIP 0000 to 1111 N/A 0000
602 ALARM 0000 to 1111 N/A 0000
603 CENTER 2.50 to 60.00 12.5 to 300.00
604 RADIUS 2.50 to 60.00 12.5 to 300.00
605 TL12 0.01 to 9.99 sec. 0.01
MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
Ω
Ω
11.00 55.00
8.50 42.50
LOSS OF EXCITATION – ZONE 2: 40-2
701 TRIP 0000 to 1111 N/A 0000
702 ALARM 0000 to 1111 N/A 0000
703 CENTER 2.50 to 60.00 12.50 to 300.0
704 RADIUS 2.50 to 60.00 12.50 to 300.0
705 TL13 0.01 to 9.99 sec. 0.01
ANTI-MOTORING #1: 32-1
801 TRIP 0000 to 1111 N/A 0000
802 ALARM 0000 to 1111 N/A 0000
803 SQ TR EN YES [1/Y]; NO [3/N] N/A YES
804 REV PWR 0.5 to 99.9 0.1 to 19.9 W 1.5 0.3
805 TL1 1 to 120 sec. 5
ANTI-MOTORING #2: 32-2
901
d
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TRIP 0000 to 1111 N/A 0000
.
Ω
Ω
11.00 55.00
8.50 42.50
2-
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DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.1 GENERAL
T able 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 3 of 7)
SETTING
NUMBER
902
d
903
d
904
d
OVERCURRENT WITH VOLTAGE RESTRAINT: 51V
1001 TRIP 0000 to 1111 N/A 0000
1002 ALARM 0000 to 1111 N/A 0000
1003 PICKUP 0.5 to 16.0 0.1 to 3.2 A 0.5 0.1
1004 TIME FAC 0.10 to 99.99 sec. 0.10
ST ATOR GROUND – ZONE 1: 64G1
1101 TRIP 0000 to 1111 N/A 0000
1102 ALARM 0000 to 1111 N/A 0000
1103 PICKUP 4.0 to 40.0 V 4.0
1104 TL4 0.1 to 9.9 sec. 0.1
ST ATOR GROUND – ZONE 2: 64G2
MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
ALARM 0000 to 1111 N/A 0000
REV PWR 0.5 to 99.9 0.1 to 19.9 W 1.5 0.3
TL2 1 to 60 sec. 1
2
1201
d
1202
d
1203
d
OVEREXCITATION – ALARM: 24A
1301 ALARM 0000 to 1111 N/A 0000
1302 PICKUP 1.0 to 1.99 per unit 1.50
1303 TL6 0 to 9.9 sec. 1.0
OVEREXCITATION – TRIP: 24T
1401 TRIP ON (-line) 0000 to 1111 N/A 0000
1402 TRIP OFF (-line) 0000 to 1111 N/A 0000
1403 ALARM 0000 to 1111 N/A 0000
1404 CURVE # 1 to 4 N/A 1
1405 INV PU 1.00 to 1.99 per unit 1.50
1406 TIME FAC 0.10 to 99.99 sec. 99.99
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TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
TL5 0.1 to 9.9 sec. 0.1
.
GE Power Management DGP Digital Generator Protection System 2-
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2.1 GENERAL 2 CALCULATION OF SETTINGS
Table 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 4 of 7)
2
SETTING
NUMBER
1407 INST PU 1.00 to 1.99 per unit 1.50
1408 TL7 0 to 9.9 sec. 1.0
1409 RESET 0 to 999 sec. 1
OVERVOLTAGE: 59
1501 TRIP 0000 to 1111 N/A 0000
1502 ALARM 0000 to 1111 N/A 0000
1503 INV PICKUP 100 to 350 de / 100 to 200
1504 TIME FAC 0.10 to 99.99 sec. 1.00
1505
e
1506
de
OVER/UNDER FREQUENCY VOLTAGE CUTOFF 81
1601 UVCUTOFF 35 to 99 % 90
UNDERFREQUENCY SETPOINT 1: 81-1U
1701 TRIP 0000 to 1111 N/A 0000
MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
f
CURVE # 1 (Inverse); 2 (Definite Time) N/A 1
INST PU 100 to 400 V 240
V120
1702 ALARM 0000 to 1111 N/A 0000
1703 SET PNT 40.00 to 65.00 Hz 60.00
1704 TL8 0.1 to 999.9 sec. 2.0
UNDERFREQUENCY SETPOINT 2: 81-2U
1801 TRIP 0000 to 1111 N/A 0000
1802 ALARM 0000 to 1111 N/A 0000
1803 SET PNT 40.00 to 65.00 Hz 60.00
1804 TL9 0.05 to 99.99 sec. 2.00
UNDERFREQUENCY SETPOINT 3: 81-3U
1901
d
1902
d
1903
d
1904
d
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TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
SET PNT 40.00 to 65.00 Hz 60.00
TL10 0.05 to 99.99 sec. 2.00
.
2-
6
DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.1 GENERAL
T able 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 5 of 7)
SETTING
NUMBER
UNDERFREQUENCY SETPOINT 1: 81-4U
2001
d
2002
d
2003
d
2004
d
OVERFREQUENCY SETPOINT 1: 81-1O
2101 TRIP 0000 to 1111 N/A 0000
2102 ALARM 0000 to 1111 N/A 0000
2103 SET PNT 45.00 to 79.99 Hz 60.00
2104 TL15 0.05 to 99.99 sec. 2.00
OVERFREQUENCY SETPOINT 2: 81-2O
2201 TRIP 0000 to 1111 N/A 0000
2202 ALARM 0000 to 1111 N/A 0000
2203 SET PNT 45.00 to 79.99 Hz 60.00
MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
SET PNT 40.00 to 65.00 Hz 60.00
TL1 1 0.05 to 99.99 sec. 2.00
2
2204 TL16 0.05 to 99.99 sec. 2.00
OVERFREQUENCY SETPOINT 3: 81-3O
2301
df
2302
df
2303
df
2304
df
OVERFREQUENCY SETPOINT 4: 81-4O
2401
df
2402
df
2403
df
2404
df
DIGITAL INPUT: DIG INP
2501 SELBKDI1 NO BLK (0); BLK #1-9 (1-9) N/A NO BLK
2502 DI3 TRIP 0000 to 1111 N/A 0000
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TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
SET PNT 45.00 to 79.99 Hz 60.00
TL17 0.05 to 99.99 sec. 2.00
TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
SET PNT 45.00 to 79.99 Hz 60.00
TL18 0.05 to 99.99 sec. 2.00
.
GE Power Management DGP Digital Generator Protection System 2-
7
Page 48
2.1 GENERAL 2 CALCULATION OF SETTINGS
Table 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 6 of 7)
2
SETTING
NUMBER
2503 DI3 ALRM 0000 to 1111 N/A 0000
2504
dg
2505
(2504g)
2506
(2505g)
2507
de
2508
e
VOLTAGE TRANSFORMER FUSE FAILURE: VTFF
2601 VTFF DISABLE (0); ENABLE (1) N/A DISABLE
ACCIDENTAL ENERGIZATION: AE
2701 TRIP 0000 to 1111 N/A 0000
2702 ALARM 0000 to 1111 N/A 0000
2703 AE ARM AND (0); OR (1) N/A AND
GROUND OVERCURRENT: 51GN
MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
DI3 TIMR
DI4 TRIP 0000 to 1111 N/A 0000
DI4 ALRM 0000 to 1111 N/A 0000
DI4 TIMR 0.00 to 9.99 sec. 0.01
DI6 FUNC EXTVTFF (0); DISPROT (1) N/A EXTVTFF
e
0.00 to 9.99 sec. 0.01
2801
e
2802
e
2803
e
2804
e
UNDERVOLTAGE: 27
2901
e
2902
e
2903
e
2903
e
2904
e
2905
e
UNDERVOLTAGE – THIRD HARMONIC: 27TN
3001
de
3002
de
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TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
PICKUP 0.10 to 5.00 0.02 to 1.00 A 0.50 0.10
TIME FAC 0.10 to 99.99 sec. 1.00
TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
PICKUP 40 to 210
PICKUP 40 to 120
TIME FAC 0.1 to 99.99 sec. 1.00
CURVE # 1 (Inverse); 2 (Definite Time) N/A 1
TRIP 0000 to 1111 N/A 0000
ALARM 0000 to 1111 N/A 0000
.
d
f
V100
V100
2-
8
DGP Digital Generator Protection System GE Power Management
Page 49
2 CALCULATION OF SETTINGS 2.1 GENERAL
T able 2–1: DGP SYSTEM SETTINGS & RATINGS (Sheet 7 of 7)
SETTING
NUMBER
3003
de
3004
de
3005
de
3006
de
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MNEMONIC RANGE DEFAULT
5 AMP 1 AMP UNITS 5 AMP 1 AMP
PICKUP 0.1 to 9.9 V 0.9
TL20 0.5 to 99.9 sec. 2.0
FORPWR-L 0 to 999 0 to 200 W 10 1
FORPWR-H 0 to 999 0 to 200 Watt 20 1
.
2
GE Power Management DGP Digital Generator Protection System 2-
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Page 50
2.2 CONFIGURATION SETTINGS 2 CALCULATION OF SETTINGS
2.2 CONFIGURATION SETTINGS 2.2.1 DESCRIPTION
101: UNITID – UNIT ID NUMBER
UNITID
with Modbus protocol ) stored in non-volati le memory that uniquely identifies a DGP relay system. When the
DGP is accessed vi a one of its serial p or ts , th e
a measure of security.
the GE-Link communication software.
2
102: SYSFREQ – SYSTEM FREQUENCY
SYSFREQ
103: SEL TVM – SELECT TRIP VOLTAGE MONITORING
One contact of each of the four tr ip outp ut re lays c an be m onitored for DC v oltage . The mo nitor ing is enable d
or disabled by sett ing
94G, 94G1, 94G2, and 94 G3, in that order. For example, a setting of 1100 enables trip voltage mo nitoring for
94G and 94G1 and disables for 94G2 and 94G3.
The monitoring of all unused contacts should be disabled to avoid nuisance alarms.
104: SEL TCM – SELECT TRIP CURRENT MONITORING
The four trip contacts de scr ibe d ab ove for the
nal is issued. This monit oring is enabled or disa bled by settin g
code of the
any of the monitored contacts is not exp ected to be above 150 mA, or if any of the trip circuit is not in ter rupte d
externally, it should be disabled to avoid nuisance sequence-of-event points or seal-in of the output relay.
is a decimal number between 0 and 9999 (for units with GE Modem protocol only) or 1 to 127 (for units
UNITID
can be set to either 50 Hz or 60 Hz.
SEL TVM
SEL TCM
setting applie s to 94G , 94G1, 94G 2, and 94 G3, in that order. If the trip cur rent throug h
can only be changed via the local MMI. It is not possible to change
to 1 or 0, res pectively. The four-digit cod e of the
UNITID
SEL TVM
is required to e sta bli s h co m mun ic ation, thus providing
SEL TVM
can also be monitored for DC c urr ent wh en a tr ip si g-
SEL TCM
to 1 or 0, respectively. The four-digit
setting applies t o
UNITID
with
For example, a setting of 1000 enables TCM for 94G and disables for 94G1, 94G2, and 94G3.
105: SELPRIM – SELECT PRIMARY/SECONDARY UNITS
SELPRIM
values (currents, voltages, watts, and vars) are displayed and stored as primary or secondary values. All userentered settings are expressed in terms of secondary values, regardless of the
106: CT RATIO – CURRENT TRANSFORMER RATIO
CT RA TIO
rent
Transformer Ratio (Setting 117:
For the sample generator system,
107: VT RATIO – VOLTAGE TRANSFORMER RATIO
VT RATIO
For the sample generator system,
can be set to either 0 (PRIMARY) or 1 (SECNDRY). This setting determines whether the pre sent
SELPRIM
can be set from 1 to 50000. This setting applies to all current inputs with a possible exception of cur-
I
If Setting 117:
NR
.
can be set from 1.0 to 240.0.
NCTRATIO
NCTRA TIO
is provided, then it app lies to the cur rent
) described later.
8000
CT RATIO
VT RATIO
==
------------ - 1600
5
18900
==
---------------- 157.5
120
I
. Refer to the Neutral Current
NR
setting.
2-
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2 CALCULATION OF SETTINGS 2.2 CONFIGURATION SETTINGS
108: COMMPORT – COMMUNICATIONS PORT
COMMPORT
number
Baud Rate =
Parity =
Stop Bits =
The baud rate sett ing of 300, 1200, 2400, 4 800, or 9600 must match t he baud rate of the modem o r serial
device connected to the RS232 serial ports . The pari ty and stop bits mus t match thos e selected for the ser ial
port of the remote PC. Norm ally, 1 stop bi t is selected. However, certain modems or other communic ations
hardware might dict ate using 2 stop bits. GE-Li nk communications softwa re can be configured to m atch the
DGP setting for baud rate, parity, and stop bits.
COMMPORT
software.
109: PHASE – PHASE DESIGNATION
PHASE
system where the DG P is in sta lled. This setting infor ms th e r el ay of the ac tual s yst em ph as e sequ enc e, eit her
A-B-C or A-C-B. The CT and VT inpu ts on the relay, labeled as A, B, and C, must be c onnected to system
phases A, B, and C for correct ope ration. This setting permits the DGP to prop erly compute and report the
sequence-dependent quantities.
110: TIMESYNC – TIME SYNCHRONIZATION SOURCE
TIMESYNC
(INTERNAL), 1 (optional, IRIG-B), or 2 (G-NET).
oscillator.
port PL-3.
to a G-NET host computer.
sets the baud rate, parity, and stop bits of the RS232 serial port. The setting format is a four-digit
xxyz
, where:
xx
= 03, 12, 24, 48, 96 (× 100)
y
= 0 (None), 1 (Odd), 2 (Even)
z
= 1, 2
can only be changed via the DGP keypad. It c annot be change d with GE-Link c ommunications
can be set to either A-B-C or A-C-B to match the positive-sequen ce phase r otation for the g enerator
determines the method of synchronizing the DGP system's internal clock. It can be set to 0
TIMESYNC
TIMESYNC
TIMESYNC
= 1 synchronizes the cl ock using an IRIG-B signal connected dire ctly to the DGP via
= 2 synchronizes the clock using a signal on pin 25 of RS232 port PL-1 when connected
= 0 lets the clock run freely from the internal
2
111: NUM FLTS – NUMBER OF FAULT EVENTS
NUM FLTS
memory without overwrit ing, and can be set to 1, 2, or 3. W hen the max imum number a re stored in m emory,
the fault report and the oscillography data associated with a subs equent storage event wil l overwrite the data
from the oldest event.
This setting also apportions a fixed amount of memory into different sized blocks for oscillography storage. The
following tabulation shows the t otal n umber of osc illogra phy cy cles a llowed per st orage even t as a f unctio n of
NUM FLTS
CAUTION
selects the maximum number of fault reports and optional oscillography data that may be stored in
.
NUM FLTS STORAGE CYCLES
1 120
2 60
3 40
To avoid loss of fault data stored in the DGP, upload and save the data before changing this
setting.
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2.2 CONFIGURATION SETTINGS 2 CALCULATION OF SETTINGS
112: PREFLT – PREFAULT CYCLES
PREFLT
1 to 20. Setting 111:
and
113: OSC TRIG – EXTERNAL OSCILLOGRAPHY TRIGGER
A DGP system trip always causes oscillography t o be stored.
2
oscillography trig ger b y an exte rnal digita l inpu t (DI5). Refer t o Sec tion 1.4 .9: FAULT REPORT & OSCILLOGRAPHY DATA on page 1–21 for further explanation.
114: NOM VOLT – NOMINAL VOLTAGE
NOM VOLT
For the sample generator system,
115: RATEDCUR – RATED CURRENT
RATEDCUR
For the sample generator system,
selects the number of pre-trigger (or pre-fault) cycles in each oscillography data set. It can be set from
PREFLT
NUM FLTS
determines how many of these are pre-trigger cycles.
can be set from 100.0 to 140.0 V (phase-to-phase).
can be set from 0.10 to 9.99 A (0.02 to 1.99 A for models with 1 A rating).
determines the total nu mbe r o f cy c les pe r st orag e ev ent , as exp la ine d ab ove ,
NOM VOLT
RATEDCUR
OSC TRIG
OSC TRIG
18000
==
---------------------------------- -
18900 120
==
---------------------------------------------------------- 4.25 A
1.732 18
⁄()
211765
×()
may be set to 0 (DI ENA) or 1 (DI DIS).
114.3 V
⁄()
8000 5
enables or disables an a dditional
116: VT CONN – VOLTAGE TRANSFORMER CONNECTION
VT CONN
ply AC voltage to the DGP.
117: NCTRATIO – NEUTRAL CURRENT TRANSFORMER RATIO
NCTRATIO
ting applies to
ting of other current inputs.
For the sample generator system,
Example Settings (based on Figure 2–1: SAMPLE GENERATOR SYSTEM):
UNITID
SYSFREQ
SEL TVM
SEL TCM
SELPRIM
CT RATIO
VT RATIO
COMMPORT
may be set to 0 (WYE) or 1 (DELTA).
setting is avail ab le in al l DG P mod el s except DGP***AAA. It c an be s et f ro m 1 to 50 000. This set-
I
current only; refer to Current Transformer Ratio (Setting 106:
NR
NCTRATIO
=1
= 60
= as required
= as required
= PRIMARY (0)
= 1600
= 157.5
= 2401
VT CONN
8000
==
------------ - 1600
5
PHASE
TIMESYNC
NUM FLTS
NOM VOLT
RA TE DCUR
VT CONN
NCTRATIO
= A-B-C (0)
= WYE (0)
must be set to identify the VT connections that sup-
2.2.2 EXAMPLE CONFIGURATION SETTINGS
= INTRNL (0)
= 3
= 114.3 volts
= 4.25 amps
= 1600
CT RA TIO
) for the CT ratio set-
2-
12
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
2.3 PROTECTION FUNCTION SETTINGS 2.3.1 TRIP AND ALARM OUTPUT RELAYS
There are eight user- configurable output relays inc luded in the DGP system. Four o f these are high-speed
relays intended for tripping and four are standard-speed relays intended for alarm. Each of the protection functions described below includes two four-digit settings,
TRIP
and
ALARM
, which configure the function to operate any number of these relays. An output relay is selected or de-selected by setting a code to 1 or 0,
respectively. The four-digit code of the
order. The four digit code of the
ALARM
TRIP
setting applies to th e 94 G, 94G1, 9 4G2, a nd 94G 3 relays , in tha t
setting applies to the 74A, 74B, 74C, and 74D relays, in that order.
2
Any number of the protection funct ions can be disabl ed by setting
both
the
TRIP
and
ALARM
codes for the
function or functions to 0000.
The configurable trip and alarm outpu ts can be used to customize the DGP in accordance wit h a number of
user-defined trip and alarm strategies.
2.3.2 STATOR DIFFERENTIAL 87G
Algorithm: Function 87G operates when the following inequality is met:
2
I1I
–
2
where: = Generator return-side phase current
I
1
I
= Generator system-side phase current
2
K
= an adaptive variable
=
K1 100⁄ if
=
15 K1×100⁄ if
KI1I
⋅()>
2
I1I
I1I
⋅81≤
2
⋅81>
2
where K1 = 87G K1 setting in percent (Setting 203: K1)
1. The algorithm is processed only if
>
I1I
– 87G PICKUP
2
2. The algorithm is processed separately for each phase.
3. The initial characteristic slope can be calculated using the formula:
% slope 100
=
--------- -
100
K1
⋅
Characteristics: Th e following four graphs show the curves fo r selected values of Setting 203: K1 and 204:
PICKUP
. The curve for any c ombination of the 203 : K1 and 204:
PICKUP
settings can be derived using the
algorithm above.
This function should be set as sensitive as practical, keeping adequate margin for CT errors under all through-
load and through-fa ult cur rent con ditions. K1 and
PICKUP
settings of 2% a nd 0.3 A, respective ly, are recommended for most applicatio ns where the system and neutral sid e CTs are of iden tical design . Higher s ettings
must be considered if the CTs are not of identical design or if a higher CT error margin is desired.
For the sample generator system, set K1 = 2% and
GE Power Management DGP Digital Generator Protection System 2-
PICKUP
= 0.3 A.
13
Page 54
2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
20
2
18
16
14
12
10
Amperes
R
I
8
6
TRIP AREA FOR
INTERNAL FAULTS
MARGIN FOR
CT ERROR
MARGIN FOR
CT ERROR
External Fault
No CT Error
(I = I )
RS
I
s
BustoGen.
4
2
0
0 2 4 6 8 10121416 1820
I
Amperes
S
I
s
Gen. to bus
I
R
I
S
G
BUS
DGP/87G
Figure 2–2: 87G CHARACTERISTICS – K1 = 1%, PICKUP = 0.3 A
2-
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
20
18
16
14
12
10
Amperes
R
I
8
6
TRIP AREA FOR
INTERNAL FAULTS
MARGIN FOR
CT ERROR
MARGIN FOR
CT ERROR
External Fault
No CT Error
(I = I )
RS
2
4
2
0
I
s
Bus to Gen.
0 2 4 6 8 10 12 14 16 18 20
I
Amperes
S
I
s
Gen. to bus
I
R
I
S
G
BUS
DGP/87G
Figure 2–3: 87G CHARACTERISTICS – K1 = 2%, PICKUP = 0.3 A
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
20
2
18
16
14
12
10
Amperes
R
I
8
6
TRIP AREA FOR
INTERNAL FAULTS
MARGIN FOR
CT ERROR
External Fault
No CT Error
(I = I )
RS
MARGIN FOR
CT ERROR
4
2
0
I
s
BustoGen.
0 2 4 6 8 10 12 14 16 18 20
Amperes
I
S
I
s
Gen. to bus
I
R
I
S
G
BUS
DGP/87G
Figure 2–4: 87G CHARACTERISTICS – K1 = 5%, PICKUP = 0.3 A
2-
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
20
18
16
14
12
10
Amperes
R
I
8
6
TRIP AREA FOR
INTERNAL FAULTS
MARGIN FOR
CT ERROR
External Fault
No CT Error
(I = I )
RS
MARGIN FOR
CT ERROR
2
I
s
BustoGen.
4
2
0
0 2 4 6 8 10121416 1820
I
Amperes
S
I
s
Gen. to bus
I
R
I
S
G
BUS
DGP/87G
Figure 2–5: 87G CHARACTERISTICS – K1 = 10%, PICKUP = 0.3 A
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
2.3.3 CURRENT UNBALANCE ALARM 46A
This function is intended to alarm prior to a 46T trip to enable an operator to take corrective action. Setting 302:
PICKUP
should be a safe margin below the generator's allowable continuous negative-sequence current.
For the sample generator system,
2
set 302: PICKUP 70% of
0.7 0.08×211765
=
----------------------------------------------------
I
capability of the machine=
2
×
×
1.732 18
380.4 A primary=
0.24 A secondary=
set 303: TL14 = 2 seconds
Algorithm:
Operating Time
T
K2
= seconds
---------------------- -
I2I
2
⁄()
FL
where
I
= Negative sequence current
2
K2 = 46T K2 setting (Setting 404: K2)
I
= Full load current of the machine (Setting 115:
FL
1. Time T is computed only if
I
> 46T PICKUP
2
2. Reset time: Linear reset (227 seconds maximum)
2.3.4 CURRENT UNBALANCE TRIP 46T
RATEDCUR
)
Characteristics: Figure 2–6: TIME CURRENT CHARACTERISTIC OF 46 T FUNCTION shows the curves for
selected values of Setting 404: K2. The curve for any other K2 setting can be derived with the above algorithm.
This function should be set at or below the negative-sequence current capability of the machine.
For the sample generator system,
I
=
capability of the machine=
2
×
-----------------------------------------------
0.08
1.732 18×1600
211765
×
set PICKUP
0.34 A secondary=
set K2 = machine capability = 10
2
I
T
2
2-
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
10000.0
1000.0
100.0
2
Time (seconds)
10.0
1.0
0.1
0.01 0.1 1 10
Negative Sequence Current / Rated Current
Time Factor K
40
30
20
10
5
2
1
Figure 2–6: TIME CURRENT CHARACTERISTIC OF 46T FUNCTION
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
2.3.5 LOSS OF EXCITATION 40, 40-1, 40-2
Algorithm: Impedance looking in to the machine is computed using delta voltage and delta current as shown in
the following equation. Functions 40-1 and 40-2 are identical, each with an adjustable time delay.
VaV
–
------------------ -
IaI
–
b
VaV
–
------------------ -
IaI
–
c
b
c
2
Z
= if Setting 109: PHASE = A-B-C
ab
Z
= if Setting 109: PHASE = A-C-B
ac
Characteristic and setting criteria: See Figure 2–7: MHO CHARACTERISTICS FOR 40-1 & 40-2 FUNCTIONS.
With settings per the criteria shown in Figure 2–7: MHO CHARACTERISTICS FOR 40-1 & 40-2 FUNCTIONS,
function 40-1 detects the loss of excitation for about 30% or higher load conditions; function 40-2 detects for all
load conditions, Howev er, some stable power system swing condit ions may mom entarily enter the 40-2 characteristic. For security of the function under stable swing conditions, it is recommended to delay functions 40-1
and 40-2 by a minimum of 0.06 and 0.5 seconds, respectively.
Setting 501:
SELV2SUP
can be set to either 0 (DISABLE ) or 1 (ENABLE). It is recommended to set th is to
function to ENABLE unless an external VTFF is used via input DI6.
For the sample generator system,
2
()
Z
secondary
b
′
(secondary) = 15.54 × 0.216 = 3.36 ohms
X
d
(secondary) = 15.54 × 1.967 = 30.57 ohms
X
d
Set 501:
SELV2SUP
kV
base
---------------------- -
=
MVA
---------------------
= = 15.54 ohms
211.765
to 1 (ENABLE).
base
18
×
2
CT Ratio
-----------------------
VT Ratio
1600
×
-------------- -
157.5
Set the 40-1 setpoints to the following values:
CENTER
RADIUS
15.54 3.36+
-------------------------------- -
2
15.54
-------------- -
2
7.77 ohms==
9.45 ohm s==
TL12 0.06 seconds=
Set the 40-2 setpoints to the following values:
CENTER
RADIUS
2-
20
TL12 0.5 seconds=
30.57 3.36+
-------------------------------- -
2
30.57
-------------- -
2
15.28 ohms==
16.97 ohms==
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
X
C1C2
40-1
40-2
C1 = Center of 40-1
= (Zb + X'd)/2
R1 = Radius of 40-1
= Zb/2
C2 = Center of 40-2
= (Xd + X'd)/2
R2 = Radius of 40-2
= Xd/2
R1
R2
X'd/2
Zb
R
2
Xd
Zb = Base impedance of the machine
X'd = Transient reactance of the machine
Xd = Synchronous reactance of the machine
Figure 2–7: MHO CHARACTERISTICS FOR 40-1 & 40-2 FUNCTIONS
2.3.6 ANTI-MOTORING (REVERSE POWER)
The 32-1 and 32-2 ant i-motoring reve rse power level se ttings 804:
REV PWR
and 903:
REV PWR
(optional,
not available in DGP***ABA models) can be set from 0.5 to 99.9 W each.
The reverse power levels (
REV PWR
) of 32-1 and 32-2 should be set at 30 to 70% (depending on power factor
following the turbine trip) of the turbine-generator motoring power .
Integrating type timers are associated with anti-motoring to achieve high level of dependability when the power
is around the
REV PWR
setting, particularl y at high power factor. If Setting 803:
SQ TR EN
(sequential trip
enable) is set t o YE S, a value of th ree seco nds o r le ss is sug gested for the ti mer T L1 as sociate d with 3 2-1. If
SQ TR EN
is set to NO, Setting 805:
TL1
should be identical to Setting 904:
TL2
described below.
Timer TL2, associated with 32-2, should be set to override the p ower swings ex pected during normal system
operations. A setting of 10 to 60 seconds is suggested.
Setting 803:
SQ TR EN
can be set to YES or NO, depending on the generator tripping strategy used.
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
For the sample generator system,
×
motoring power
REV PWR
Set
to:
×
=
22000 1000
------------------------------------------------------------- -
CT RATIO VT RATIO
×
watts
22000 1000
==
----------------------------------- - watts 87.3 watts
×
1600 157.5
2
REV PWR
TL1
Set
Set
to:
TL1
= 2 or 30 seconds, depending on Setting 803:
TL2
to:
TL2
= 30 seconds
Algorithm:
=
T
------------------------------------ -
where:
T
K
I/I
V
V = for Wye connected VTs (see note 2)
= 0.5 × 87.3 (functions 32-1 and 32-2)
= 43.6 watts
2.3.7 OVERCURRENT WITH VOLTAGE RESTRAINT (51V)
K
⁄
II
PU
---------------------- - 1
⁄
VV
NOM
seconds
–
= Operating time.
= time factor (Setting 1004:
= current in multiple of
PU
= Nominal Voltage (Setting 114:
NOM
×
3 phase-to-ground voltage
TIME FAC
I
(Setting 1003:
PU
NOM VOLT
).
phase-to-phase voltage for Delta connected VTs
SQ TR EN
PICKUP
)
.
).
1. Time
T
is computed individually for each phase.
2. See the table below for the restraint voltages corresponding to phase currents for different
109) and
3. If the quantity
4. If the quantity , then 65.5 is used as its value in the equation.
VT CONN
V/V
⁄
II
---------------------- -
⁄
VV
(Setting 116) settings.
< 0.3, then 0.3 is used as its value in the equation.
NOM
PU
<
0.3
NOM
5. Reset Time: Linear reset with maximum of 1.4 seconds.
Table 2–2: 51V RESTRAINT VOLTAGES
CURRENT RESTRAINT VOLTAGES
→
→
I
A
I
B
I
C
ABC
WYE
V
A
V
B
V
C
ABC
DELTA
V
AB
V
BC
V
CA
ACB
WYE
V
A
V
B
V
C
ACB
DELTA
V
AC
V
BA
V
CB
PHASE
VT
PHASE
(Setting
2-
22
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
Characteristics: The following four graphs show the curves for selected values of K and Voltage Restraint. The
curve for any combination of
This function shoul d be set to coordi nate with the powe r system prote ctive relays us ed at the gener ating station. Also, the
Refer to Section 2.3.19: ACCIDENTAL ENERGIZA TION AE on page 2–37 for additional considerations regarding the 51V
PICKUP
PICKUP
setting.
K
and Restraint Voltage can be determined with the above algorithm.
setting should be a safe margin above the expe cted maximum load on the machine.
For the sample generator system,
PICKUP
set
Setting 1004:
ing station. As the information about line re la ys is no t k nown , se t
for a 3-phase fault on the high side of the GSU is about 0.75 second. For simplicity, power system contribution
to the fault is not considered in the following calculations.
Impedance to fault 21.6 10
Generator contribution = 4.25 / 0.322 = 13.2 A secondary
Multiple of
Generator terminal voltage =
% restraint =
TIME FAC
set
= 1.75 × generator rated load current
= 1.75 × 4.25 A
= 7.5 A secondary
TIME FAC
PICKUP
5.93
-----------
(K) =
TIME FAC
(
K
) should be selected to back up the relays on transmission lines out of the generat-
211.765
===
= 13.2 / 7.5 = 1.76
18
0.75
= 1.0
+
×
---------------------
18
=
100×32.9%
1.76
×
-------------- - 1
0.329
×
–
10.6
-----------
32.2
200
21.6 10.6+32.2 % at machi ne base
5.93= kV
=
0.985 or higher
TIME FAC
such that the operat e ti me o f 51V
2
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2
2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
10
Time Factor K
4
3
1
Time (seconds)
0.1
2
1
0.5
0.25
0.01
0.1 1 10
Multiple of Pickup Setting
Figure 2–8: 51V TIME-CURRENT CHARACTERISTICS FOR 0 TO 30% RESTRAINT
2-
24
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
10
1
Time (seconds)
Time Factor K
4
3
2
1
0.5
0.25
2
0.1
0.01
0.1 1 10
Multiple of Pickup Setting
Figure 2–9: 51V TIME-CURRENT CHARACTERISTICS FOR 50% RESTRAINT
GE Power Management DGP Digital Generator Protection System 2-
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
10
2
1
Time (seconds)
Time Factor K
4
3
2
1
0.5
0.25
0.1
0.01
0.1 1 10
Multiple of Pickup Setting
Figure 2–10: 51V TIME-CURRENT CHARACTERISTICS FOR 75% RESTRAINT
2-
26
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
10
Time Factor K
4
3
2
2
1
Time (seconds)
0.1
1
0.5
0.25
0.01
0.1 1 10
Multiple of Pickup Setting
Figure 2–11: 51V TIME-CURRENT CHARACTERISTICS FOR 100% RESTRAINT
GE Power Management DGP Digital Generator Protection System 2-
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
Algorithm: 64G-1 operates if following condition is met:
≥
2
V
N1
where:
PICKUP
for time > TL4 seconds
V
= Neutral voltage of fundamental frequency
N1
PICKUP
TL4
= 64G-1 pickup setting
= timer TL4 setting
2.3.8 STATOR GROUND FAULT 64G-1
Setting 1103:
PICKUP
of 64G-1 should be set wit h a saf e ma rgin abo ve the hig hest vol tage ( fundame ntal frequency) expected at the gen erator neutral un der norma l operating co nditions . Timer TL4 should be set with a
safe margin above the longest clearing time for power system faults that are outside of the generator protection
zone.
For the sample generator system,
set 1 1 03:
set 1 1 04:
PICKUP
TL4
= 5.0 volts
= 1 second or higher
2.3.9 STATOR GROUND FAULT 64G-2
Algorithm: 64G-2 operates when the following condition is met:
V
3
V
3
P
N
⁄()
3
-------------------------------------- - 0.15 for time >TL5 seconds
The only setting r eq ui red for this optional fun cti on is fo r ti mer TL 5 ( Se tti ng 1203 :
≤
V
+
3
N
TL5
) to provide a sho rt delay
for security of the function.
For the sample generator system,
set 1203:
TL5
= 0.10 second.
2.3.10 STATOR GROUND FAULT 27TN
Algorithm: 27TN operates when the following conditions are met (see Figure 1–5: SIMPLE LOGIC DIAGRAM –
64G1, 64G2, 51GN, AND 24 on page 1–14 for the logic diagram):
V
< 27TN PICKUP and
N3
where:
Setting 1302:
V
= Third harmonic voltage at generator neutral.
N3
V
= Positive sequence voltage at generator terminals.
1
TL20 = Timer TL20 (Setting 3004:
PICKUP
should be set as sensitive as the
V
> 25V for time > TL20
1
TL20
).
V
characteristic of the generator allows without loss
N3
of security. A flexible window of power c an be es tablis he d to en hanc e se cu ri ty of 27T N. Fo r ex am pl e, a ssum e
that the available
dow is provided by S ettings 3005:
V
is below 27TN p icku p for p ower outp uts in the r an ge of 50 to 80 wa tts . The flexible win-
N3
FORPWR-L
and 3006:
FORPWR-H
, which can be set at 47 an d 85 watts
(based on margin of about 5%) respectively to inhibit the function between the limits. This function can also be
blocked when the generator is off-line; refer to Setting 2501:
2-
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DGP Digital Generator Protection System GE Power Management
SELBKDI1
.
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
2.3.11 OVEREXCITATION ALARM (VOLTS/HERTZ: 24A)
This function is i ntended to alarm prior to a 24T trip, allowing an oper ator to take corrective actio n. Setting
PICKUP
1302:
ever is lower. Timer TL6 (Setting 1303:
should be below the con tinuous Volts/Hz rating of the generator or step -u p tr ansfo rm er, which-
TL6
) should be set to minimize the nuisance alarms.
For the sample generator system, assume an allowable over V/Hz of 10%.
PICKUP
set
set
TL6
= 1 + (90% of 10%) per unit = 1.09 per unit
= 2 seconds.
2.3.12 OVEREXCITATION TRIP (VOLTS/HERTZ: 24T)
Algorithm:
2
=
-------------------------------------------------------------- - seconds
T
1
---------------------------------------------
PU
--------------------------------------------------
=
T
2
---------------------------------------- 1
PU
=
------------------------------------------------------------------ - seconds
T
3
---------------------------------------------
PU
=
T
4
K
seconds
⁄
VF
V
NOMFS
K
⁄
VF
V
NOMFS
⁄
VF
V
NOMFS
K
2
–
⁄()×
1
seconds
–
⁄×
K
0.5
–
⁄()×
1
where
T1 = Operating time for CURVE #1 (see Figure 2–12: TIME CHARACTERISTICS OF FUNCTION 24T
(CURVE 1) on page 2–31)
T2 = Operating time for CURVE #2 (see Figure 2–13: TIME CHARACTERISTICS OF FUNCTION 24T
(CURVE 2) on page 2–32)
T3 = Operating time for CURVE #3 (see Figure 2–14: TIME CHARACTERISTICS OF FUNCTION 24T
(CURVE 3) on page 2–33)
T4 = Operating time for CURVE #4 - characteristic of curve #4 is definite time providing the operating time
equal to K seconds if
V
--- - PU
F
K
= Time factor (Setting 1406:
V
= nominal voltage (Setting 114:
NOM
F
= system frequency (Setting 102:
S
PU = V/Hz pickup (Setting 1405:
V
×>
-------------- -
NOM
F
S
TIME FAC
NOM VOLT
SYSFREQ
INV PU
)
)
)
)
1. The algorithm is processed separately for each phase.
2.
V
and
V
values used are phase- ground v oltage s for wye- conn ected VTs. However, p hase- phase volt-
NOM
ages are used for delta-co nnected VTs. The following table shows the voltages used by each of the three
GE Power Management DGP Digital Generator Protection System 2-
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
phases for different phase designations (Setting 109:
CONN
).
PHASE
) and VT connections (Setting 116:
Table 2–3: 24A VOLTAGES
PHASE VOLTAGES
VT
A
B
C
→
→
ABC
WYE
V
A
V
B
V
C
ABC
DELTA
V
AB
V
BC
V
CA
ACB
WYE
V
A
V
B
V
C
ACB
DELTA
V
V
V
RESET
AB
BC
CA
setting (Setting 1409).
2
PHASE
3. Reset time: Linear reset with maximum time =
This function should be set wi th a safe margin below the excitation capabilit y of the generator or step-u p
transformer, whichever is lower. The following example is based on the tradi tional criteria of 45 seconds
operating time at V/Hz from 1.1 to 1.18 per unit. However, actual excitation cap ability curves should b e
obtained for the gene rator and the transform er to take full advanta ge of the inverse char acteristic of this
function. Setting 1 409:
RESET
should be set to match the coolin g characteristic of the protected equi pment (if known). If the reset characteristic is not available, a setting in the range of 0 to 50 seconds may be
used.
For the sample generator system, using CURVE #4 (definite time) and operating time of 45 seconds:
VT
INV PU
set
TIME FAC
set
INST PU
set
TL7
set
RESET
set
= 1.10 per unit
= 45 seconds
= 1.18 per unit
= 2 seconds
= 30 seconds
2-
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DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
100
Time Factor K
10
8
6
2
10
Time (seconds)
1
4
2
1.0
0.5
0.1
1 1.1 1.2 1.3
Multiple of "INV PU"
Figure 2–12: TIME CHARACTERISTICS OF FUNCTION 24T (CURVE 1)
GE Power Management DGP Digital Generator Protection System 2-
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
100
Time Factor K
2
10
8
6
4
2
10
1.0
Time (seconds)
0.5
1
0.1
1 1.1 1.2 1.3
Multiple of "INV PU"
Figure 2–13: TIME CHARACTERISTICS OF FUNCTION 24T (CURVE 2)
2-
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
Time Factor K
100
10
8
6
4
2
10
1.0
2
0.5
Time (seconds)
1
0.1
1 1.1 1.2 1.3
Multiple of "INV PU"
Figure 2–14: TIME CHARACTERISTICS OF FUNCTION 24T (CURVE 3)
GE Power Management DGP Digital Generator Protection System 2-
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2
2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
2.3.13 OVERVOLTAGE 59
Algorithm:
T1
T2 =
V
---------- 1
V
K
seconds
1
PU
seconds
–
K
------------------- -
=
T3 = no intentional time delay
where:
T1 = Operating time for
T2 = Operating time for
operating time equal to K seconds if
T3 = Operating time of optional instantaneous function if
K
= time factor (Setting 1504:
V
= positive-sequence voltage (phase-phase)
1
V
= overvoltage pickup (Setting 1503:
PU
V
= instantaneous overvoltage pickup (Setting 1506:
IPU
CURVE #1
CURVE #2
TIME FAC
(see Figure 2–15: 59 TIME-VOLTAGE CHARACTERISTICS)
(the characteristic of optio nal curve #2 is definite time providi ng the
V
>
V
PU
)
V1 > V
PU
1
)
INV PICKUP
)
INST PU
)
Reset Time: Linear reset (1.4 seconds maximum)
Characteristics: Figure 2–15: 59 TIME-VOLTAGE CHARACTERISTICS shows the CURVE #1 for selected values of
K
. The curve for any other K setting can be derived using the above algorithm.
This function should be set wi th a safe margin below the overvoltag e capability of the protected equip ment.
Function 59 can provide backup to function 24T.
For the sample gen erator s yste m, set 59 us ing c riter i a s imil ar to 24T s ett ing s ex ce pt wi th lowe r se ns iti vit y an d
higher operating time.
Set
V
= 1.1 ×
PU
For determining the time factor
115% of
PICKUP
NOM VOLT
voltage.
= 1.1 × 114.3 = 126 volts
K
(assuming CURVE #1 is used), use an operating time of about 45 seconds at
Voltage (
Time Factor
2-
34
V
) = 1.15 × 126 = 144.9 volts
144.9
=
⋅
45
K
–
-------------- - 1
126
DGP Digital Generator Protection System GE Power Management
=
6.75
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
1000
100
Time Factor K
2
10
10
Time (seconds)
1
0.1
100 110 120 130 140 150 160 170 180 190 200
Percent of Pickup
7
5
4
3
2
1.0
0.5
Figure 2–15: 59 TIME-VOLTAGE CHARACTERISTICS
GE Power Management DGP Digital Generator Protection System 2-
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
2.3.14 UNDERVOLTAGE CUTOFF OF 81
Setting 1601:
setting can be used to block the frequency functions from operating during start-up conditions until near-normal
generator field is applied and set voltage is generated.
UVCUTOFF
can be set from 35 to 99% of the nom inal volta ge (Setting 114:
2.3.15 UNDERFREQUENCY 81-U
NOM VOLT
2
There are either two or four underfrequency functions included with the DGP, depending on the model. Each of
the functions (Set tin gs 1703/1803/1903/2003:
of 0.1 to 999.9 seconds fo r 81-1U a nd 0.05 to 99. 99 seconds f or the othe r(s). The actu al setting s will depen d
on the protection and operating philosophies of the individual user.
There are either two or four overfrequency functions included in the DGP, depending on the model. Each of the
functions (Settings 2103/ 2203/2303/2403 :
0.05 to 99.99 seconds. The actual settings will depend on the protection and operating philosophies of the individual user.
Setting 2501:
gized. It is set from 0 to 9 de pending on the p rotection functions to be blocked during the start-up. The tabl e
below describes the different blocking actions:
Table 2–4: DI1 BLOCKING CONFIGURATION
SELBKDI1
determines the blocking action by digital input DI1 (generator off-line) when it is ener-
SET PNT
SET PNT
) can be set from 40.0 0 to 6 5.0 0 Hz , wit h a ti me del ay
2.3.16 OVERFREQUENCY 81-O
) can be set from 45 .00 to 79.99 Hz, wi th a time dela y of
2.3.17 DIGITAL INPUT DI
). This
SELBKDI1 FUNCTIONS DISABLED (X) BY DI1
81 32
NO BLK (0) - - - BLK #1 (1)
BLK #2 (2)
BLK #3 (3)
BLK #4 (4)
BLK #5 (5) BLK #6 (6)
BLK #7 (7) BLK #8 (8)
BLK #9 (9)
1
Refer to the Nomenclature Guide for available functions
Note that for DGP***ABA models, some of the
settings may be used to obtain the specified functionality.
X
X
X
XX
XX
X
XX X X
--
-
-
X
XXX
---
64G2 / 27TN
SELBKDI1
X
XX
settings are functionally redundant; any one of such
1
--
-
-
VTFF
X
-
X
X
2-
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DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
An appropriate combination of functions 81, 32, 64G2, 27TN, and VTFF should be blocked during start-up
(generator off-line) as required. For example, to prevent nuisance operati on, Setti ng 25 01:
set as follows:
• BLK #6 to block 81, 32, and VTFF for cross compound machine.
• BLK #8 to block 81 if generator field is a pplied at a speed l ower than the speed c orresponding to lowest
81U setpoint.
SELBKDI1
may be
• BLK #9 to block all four functions for a gas turbine generator with static start.
Settings 2502:
ate any or all of the Trip (94G to 94G3) or Alarm (74A to 74D) relays. If the settings are selected, energizing the
corresponding digi tal i nput w ill ca use the appro priate Trip and Alarm rel ay to operate after tim e del ay, if applicable.
Setting 2508:
(EXTVTFF), the DI6 is configured to receive an external VTFF si gnal. If set to 1 (DISPROT), the DI6 is configured to disable all protection functions as long as the input signal is present. It should be set to 0 (EXTVTFF) if
the input DI6 is not used.
Setting 2601:
VTFF
= 1 (ENABLE) if the external VTFF input (DI6) is n ot used. If the external VTFF input is used, the
setting will depend on user preference.
Setting 2703:
when the positive sequence voltage V1 < 30 volts
be armed when the voltage V1 < 30 volts
However, if
DI3 TRIP
DI6 FUNC
VTFF
AE ARM
both
of the following conditions apply, it must be set to 1 (OR) for effective arming of the logic.
, 2503:
can be set to eithe r 0 (DISABLE) or 1 (ENAB LE) as desired. It is r ecommended to set
can be set to 0 (AND) or 1 ( OR) as desired . If set to 0 (AND), the logic will be ar med
DI3 ALARM
can be set to 0 (EXTVTFF) or 1 (DISPROT) to configure the DI6 input. If set to 0
, 2504/5:
or
the generator is off-line. The setting o f 0 (AND) is re comme nded.
DI4 TRIP
2.3.18 VOLTAGE TRANSFORMER FUSE FAILURE VTFF
and
the generator is off-line. If it is set to 1 (OR), the logic will
, and 2505/6:
2.3.19 ACCIDENTAL ENERGIZATION AE
DI4 ALARM
can be used to oper-
VTFF
2
• The generator system includes a generator disconnect device (breaker or switch),
• The VTs are connected on the power system side of the disconnect device.
Since the pickup flag of functio n 51V i s used fo r inst antaneous overcu rrent si gnal in the Ac cidental Energization logic (Figure 1–3: SIMPLE LOGIC DIAGRAM – 87G, 32, 27, 59, AND AE on page 1–12), the fol lowing
additional criteria should be used in setting the 51V PICKUP.
The 51V PICKUP (Setting 1003 :
expected maximum load cu rrent of the machine. If Setting 2703:
loss of all three phase voltages is likely, then
Note that function AE will be effectively disabled if function 51V is disabled by setting both its
ALARM
by setting its
For the sample generator system,
set
codes (Settings 1001 and 1002) to 0000. This is in addition to the normal way of disabling function AE
AE ARM
TRIP
= 0 (AND)
and
ALARM
PICKUP
codes (Settings 2701 and 2702) to 0000.
) should be set with a safe mar gin above
AE ARM
PICKUP
should be set with a safe margin above 3.33 ×
is set to 1 (OR) and simultaneous
and
I
LMAX
, where
I
LMAX
I
TRIP
is an
LMAX
.
and
GE Power Management DGP Digital Generator Protection System 2-
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2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
2.3.20 GROUND OVERCURRENT 51GN
Algorithm:
---------------------------------- seconds=
I
NRIPU
K
⁄
TIME FAC
current
1–
)
2
Operating Time
T
where:
K
= time factor (Setting 2804:
I
= Neutral current (fundamental frequency)
NR
I
= Setting 2803:
PU
PICKUP
Reset Time: Linear reset (1.4 seconds maximum)
Characteristics: Figure 2–16: 51GN TIME-CURRENT CHARACTERISTICS shows the curves for selected values of
K
. The curve for any other value of K can be derived using the above algorithm.
Setting 2803:
tal frequency) expected unde r normal operating con ditions. Setting 280 4:
PICKUP
of 51GN should be set with a safe margin above the highest neutral current (fundamen-
TIME FAC
should be set to c oordi-
nate with other protective devices for power system faults that are outside of the generator protection zone.
For the sample gene ra tor s y ste m, functi on 51G N is n ot usabl e, due to the high resistance g ro und ing an d hig h
CT ratio for the function. Set Settings 2801:
TRIP
and 2802:
ALARM
to 0000 to disable the function.
2.3.21 UNDERVOLTAGE 27
Algorithm:
T1
K
-----------------------------------
⁄()
V
V
1
PU
seconds=
1–
where:
T1= operating time for CURVE #1 (Figure 2–17: 27 TIME-VOLTAGE CHARACTERISTICS on page 2–40)
T2= operating time for CURVE #2 (t he characte rist ic of CURVE #2 is de finite ti me pro viding th e operatin g
time is equal to
V
= positive-sequence voltage (phase-phase).
1
V
= undervoltage function threshold (Setting 2903:
PU
K
seconds if
V
<
V
PU
)
PICKUP
).
1
Reset Time: Linear reset (1.4 seconds maximum)
The algorithm is NOT processed if input DI1 (generator off-line) is present.
Characteristics: Figure 2–17: 27 TIME-VOLTAGE CHARACTERISTICS shows the CURVE #1 for selected val-
ues of
K
. The curve for any othe r K setting can be derive d using the above algor ithm. This optional func tion
can be used to isolate the generator from the utility system for an undervoltage condition. Settings 2905:
CURVE #
, 2903:
PICKUP
, and 2904:
TIME FAC
should be set to override voltage dips caused by normal
power system faults.
For the sample generator system, 27 can be set as follows:
CURVE #
PICKUP
TIME FAC
= 2 (Definit e Time)
= 102 V (< 90% of
= 1.0 second
NOM VOLT
of 114.3 V)
2-
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DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.3 PROTECTION FUNCTION SETTINGS
10
Time Factor K
10
9
8
7
6
2
5
1
Time (seconds)
0.1
110100
Multiple of Pickup Setting
4
3
2
1
Figure 2–16: 51GN TIME-CURRENT CHARACTERISTICS
GE Power Management DGP Digital Generator Protection System 2-
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Page 80
2
2.3 PROTECTION FUNCTION SETTINGS 2 CALCULATION OF SETTINGS
10
1
Time (seconds)
Time Factor K
10
9
8
7
6
5
4
3
2
1
0.1
1 10 100
Percent of Pickup
Figure 2–17: 27 TIME-VOLTAGE CHARACTERISTICS
2-
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DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
2.4 COMMISSIONING 2.4.1 DGP
***
Table 2–5: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ AAA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
CONFIGURATION: CONFIG
101 UNITID Unit ID number
102 SYSFREQ System Frequency Hz
103 SEL TVM Select Trip Voltage Monitoring
104 SEL TCM Select Trip Current Monitoring
105 SELPRIM Select Primary/Secondary units
106 CT RATIO Current Transformer Ratio
107 VT RATIO Voltage Transformer Ratio
108 COMMPORT Communications Port
109 PHASE Phase Rotation
AAA SETTINGS TABLE (Sheet 1 of 5)
***
AAA SETTINGS TABLE
2
110 TIMESYNC Time Synchronizing source
111 NUM FLTS Number of Fault events stored
112 PREFLT Number of prefault cycles stored Cycles
113 OSC TRIG External oscillography trigger
114 NOM VOLT Nominal Voltage of generator Volts
115 RATEDCUR Rated Current of generator Amps
116 VT CONN Type of VT connection
STATOR DIFFERENTIAL: 87G
201 TRIP Configure trip outputs
202 ALARM Configure alarm outputs
203 K1 K factor %
204 PICKUP Pickup level Amps
CURRENT UNBALANCE – ALARM: 46A
301 ALARM Configure alarm outputs
302 PICKUP Pickup current (Negative sequence) Amps
303 TL14 Timer TL14 setting Sec.
CURRENT UNBALANCE – TRIP: 46T
401 TRIP Configure trip outputs
GE Power Management DGP Digital Generator Protection System 2-
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2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
Table 2–5: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ AAA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
402 ALARM Configure alarm outputs
2
403 PICKUP Pickup current (Negative sequence) Amps
404 K2 K factor Sec.
LOSS OF EXCITATION – SUPERVISION: 40
501 SELV2SUP Select V2 supervision of 40
LOSS OF EXCITATION – ZONE 1: 40-1
601 TRIP Configure trip outputs
602 ALARM Configure alarm outputs
603 CENTER Center of characteristic Ohms
604 RADIUS Radius of characteristic Ohms
***
AAA SETTINGS TABLE (Sheet 2 of 5)
605 TL12 Timer TL12 setting Sec.
LOSS OF EXCITATION – ZONE 2: 40-2
701 TRIP Configure trip outputs
702 ALARM Configure alarm outputs
703 CENTER Center of characteristic Ohms
704 RADIUS Radius of characteristic Ohms
705 TL13 Timer TL13 setting Sec.
ANTI-MOTORING #1: 32-1
801 TRIP Configure trip outputs
802 ALARM Configure alarm outputs
803 SQ TR EN Enable sequential trip
804 REV PWR Reverse power pickup Watts
805 TL1 Timer TL1 setting Sec.
ANTI-MOTORING #2: 32-2
901 TRIP Configure trip outputs
902 ALARM Configure alarm outputs
903 REV PWR Reverse power pickup Watts
904 TL2 Timer TL2 setting Sec.
OVERCURRENT WITH VOLTAGE RESTRAINT: 51V
1001 TRIP Configure trip outputs
2-
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DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
***
Table 2–5: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ AAA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
1002 ALARM Configure alarm outputs
1003 PICKUP Pickup current Amps
1004 TIME FAC Time factor Sec.
ST ATOR GROUND – ZONE 1: 64G1
1101 TRIP Configure trip outputs
1102 ALARM Configure alarm outputs
1103 PICKUP Pickup voltage Volts
1104 TL4 Timer TL4 setting Sec.
ST ATOR GROUND – ZONE 1: 64G2
1201 TRIP Configure trip outputs
AAA SETTINGS TABLE (Sheet 3 of 5)
2
1202 ALARM Configure alarm outputs
1203 TL5 Timer TL5 setting Sec.
OVEREXCITATION – ALARM: 24A
1301 ALARM Configure alarm outputs
1302 PICKUP Pickup (V/Hz) Per Unit
1303 TL6 Timer TL6 setting Sec.
OVEREXCITATION – TRIP: 24T
1401 TRIP ON Configure trip outputs (on-line)
1402 TRIP OFF Configure trip outputs (off-line)
1403 ALARM Configure alarm outputs
1404 CURVE # Curve number (Inverse characteristic)
1405 INV PU Pickup - V/Hz (Inverse characteristic) Per Unit
1406 TIME FAC Time factor Sec.
1407 INST PU Pickup - V/Hz (Instantaneous) Per Unit
1408 TL7 Timer TL7 setting Sec.
1409 RESET Reset time Sec.
OVERVOLTAGE: 59
1501 TRIP Configure trip outputs
1502 ALARM Configure alarm outputs
1503 PICKUP Inverse function pickup voltage (positive- sequence) Volts
GE Power Management DGP Digital Generator Protection System 2-
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2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
Table 2–5: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ AAA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
1504 TIME FAC Time factor Sec.
2
OVER/UNDER FREQUENCY VOLTAGE CUTOFF: 81
1601 UVCUTOFF Undervoltage cutoff level for functions 81 Volts
UNDERFREQUENCY SETPOINT 1: 81-1U
1701 TRIP Configure trip outputs
1702 ALARM Configure alarm outputs
1703 SET PNT Set point Hz
1704 TL8 Timer TL8 setting Sec.
UNDERFREQUENCY SETPOINT 2: 81-2U
1801 TRIP Configure trip outputs
***
AAA SETTINGS TABLE (Sheet 4 of 5)
1802 ALARM Configure alarm outputs
1803 SET PNT Set point Hz
1804 TL9 Timer TL9 setting Sec.
UNDERFREQUENCY SETPOINT 3: 81-3U
1901 TRIP Configure trip outputs
1902 ALARM Configure alarm outputs
1903 SET PNT Set point Hz
1904 TL10 Timer TL10 setting Sec.
UNDERFREQUENCY SETPOINT 4: 81-4U
2001 TRIP Configure trip outputs
2002 ALARM Configure alarm outputs
2003 SET PNT Set point Hz
2004 TL11 Timer TL11 setting Sec.
OVERFREQUENCY SETPOINT 1: 81-1O
2101 TRIP Configure trip outputs
2102 ALARM Configure alarm outputs
2103 SET PNT Set point Hz
2104 TL15 Timer TL15 setting Sec.
OVERFREQUENCY SETPOINT 2: 81-2O
2201 TRIP Configure trip outputs
2-
44
DGP Digital Generator Protection System GE Power Management
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2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
Table 2–5: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ AAA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
2202 ALARM Configure alarm outputs
2203 SET PNT Set point Hz
2204 TL16 Timer TL16 setting Sec.
OVERFREQUENCY SETPOINT 3: 81-3O
2301 TRIP Configure trip outputs
2302 ALARM Configure alarm outputs
2303 SET PNT Set point Hz
2304 TL17 Timer TL17 setting Sec.
OVERFREQUENCY SETPOINT 4: 81-4O
2401 TRIP Configure trip outputs
2402 ALARM Configure alarm outputs
2403 SET PNT Set point Hz
***
AAA SETTINGS TABLE (Sheet 5 of 5)
2
2404 TL18 Timer TL18 setting Sec.
DIGITAL INPUT: DIG INP
2501 SELBKDI1 Select blocking action by input DI1
2502 DI3 TRIP Configure trip outputs
2503 DI3 ALRM Configure alarm outputs
2504 DI4 TRIP Configure trip outputs
2505 DI4 ALRM Configure alarm outputs
VOLTAGE TRANSFORMER FUSE FAILURE: VTFF
2601 VTFF Enable/Disable VTFF
ACCIDENTAL ENERGIZATION: AE
2701 TRIP Configure trip outputs
2702 ALARM Configure alarm outputs
2703 AE ARM Arming logic, Accidental Energization
GE Power Management DGP Digital Generator Protection System 2-
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2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
2.4.2 DGP***ABA SETTINGS TABLE
***
Table 2–6: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ABA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
ABA SETTINGS TABLE (Sheet 1 of 5)
2
SETTING # MNEMONIC DESCRIPTION USER SETTING
CONFIGURATION: CONFIG
101 UNITID Unit ID number
102 SYSFREQ System Frequency Hz
103 SEL TVM Select Trip Voltage Monitoring
104 SEL TCM Select Trip Current Monitoring
105 SELPRIM Select Primary/Secondary units
106 CT RATIO Current Transformer Ratio
107 VT RATIO Voltage Transformer Ratio
108 COMMPORT Communications Port
109 PHASE Phase Rotation
110 TIMESYNC Time Synchronizing source
111 NUM FLTS Number of Fault events stored
114 NOM VOLT Nominal Voltage of generator Volts
115 RATEDCUR Rated Current of generator Amps
116 VT CONN Type of VT connection
117 NCTRATIO Current Transformer Ratio (Neutral)
STATOR DIFFERENTIAL: 87G
201 TRIP Configure trip outputs
202 ALARM Configure alarm outputs
203 K1 K factor %
204 PICKUP Pickup level Amps
CURRENT UNBALANCE – ALARM: 46A
301 ALARM Configure alarm outputs
302 PICKUP Pickup current (Negative sequence) Amps
303 TL14 Timer TL14 setting Sec.
CURRENT UNBALANCE – TRIP: 46T
401 TRIP Configure trip outputs
402 ALARM Configure alarm outputs
2-
46
DGP Digital Generator Protection System GE Power Management
Page 87
2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
Table 2–6: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ABA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
403 PICKUP Pickup current (Negative sequence) Amps
404 K2 K factor Sec.
LOSS OF EXCITATION – SUPERVISION: 40
501 SELV2SUP Select V2 supervision of 40
LOSS OF EXCITATION – ZONE 1: 40-1
601 TRIP Configure trip outputs
602 ALARM Configure alarm outputs
603 CENTER Center of characteristic Ohms
604 RADIUS Radius of characteristic Ohms
605 TL12 Timer TL12 setting Sec.
LOSS OF EXCITATION – ZONE 2: 40-2
701 TRIP Configure trip outputs
***
ABA SETTINGS TABLE (Sheet 2 of 5)
2
702 ALARM Configure alarm outputs
703 CENTER Center of characteristic Ohms
704 RADIUS Radius of characteristic Ohms
705 TL13 Timer TL13 setting Sec.
ANTI-MOTORING: 32-1
801 TRIP Configure trip outputs
802 ALARM Configure alarm outputs
803 SQ TR EN Enable sequential trip
804 REV PWR Reverse power pickup Watts
805 TL1 Timer TL1 setting Sec.
OVERCURRENT WITH VOLTAGE RESTRAINT: 51V
1001 TRIP Configure trip outputs
1002 ALARM Configure alarm outputs
1003 PICKUP Pickup current Amps
1004 TIME FAC Time factor Sec.
ST ATOR GROUND – ZONE 1: 64G1
1101 TRIP Configure trip outputs
1102 ALARM Configure alarm outputs
GE Power Management DGP Digital Generator Protection System 2-
47
Page 88
2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
Table 2–6: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ABA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
1103 PICKUP Pickup voltage Volts
2
1104 TL4 Timer TL4 setting Sec.
OVEREXCITATION – ALARM: 24A
1301 ALARM Configure alarm outputs
1302 PICKUP Pickup (V/Hz) Per Unit
1303 TL6 Timer TL6 setting Sec.
OVEREXCITATION – TRIP: 24T
1401 TRIP ON Configure trip outputs (on-line)
1402 TRIP OFF Configure trip outputs (off-line)
1403 ALARM Configure alarm outputs
***
ABA SETTINGS TABLE (Sheet 3 of 5)
1404 CURVE # Curve number (Inverse characteristic)
1405 INV PU Pickup - V/Hz (Inverse characteristic) Per Unit
1406 TIME FAC Time factor Sec.
1407 INST PU Pickup - V/Hz (Instantaneous) Per Unit
1408 TL7 Timer TL7 setting Sec.
1409 RESET Reset time Sec.
OVERVOLTAGE: 59
1501 TRIP Configure trip outputs
1502 ALARM Configure alarm outputs
1503 PICKUP Inverse function pickup voltage (positive- sequence) Volts
1504 TIME FAC Time factor Sec.
1505 CURVE# Curve Number (1 = Inverse; 2 = Definite Time)
OVER/UNDER FREQUENCY VOLTAGE CUTOFF: 81
1601 UVCUTOFF Undervoltage cutoff level for functions 81 Volts
UNDERFREQUENCY SETPOINT 1: 81-1U
1701 TRIP Configure trip outputs
1702 ALARM Configure alarm outputs
1703 SET PNT Set point Hz
1704 TL8 Timer TL8 setting Sec.
2-
48
DGP Digital Generator Protection System GE Power Management
Page 89
2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
***
Table 2–6: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ABA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
UNDERFREQUENCY SETPOINT 2: 81-2U
1801 TRIP Configure trip outputs
1802 ALARM Configure alarm outputs
1803 SET PNT Set point Hz
1804 TL9 Timer TL9 setting Sec.
OVERFREQUENCY SETPOINT 1: 81-1O
2101 TRIP Configure trip outputs
2102 ALARM Configure alarm outputs
2103 SET PNT Set point Hz
2104 TL15 Timer TL15 setting Sec.
ABA SETTINGS TABLE (Sheet 4 of 5)
2
OVERFREQUENCY SETPOINT 2: 81-2O
2201 TRIP Configure trip outputs
2202 ALARM Configure alarm outputs
2203 SET PNT Set point Hz
2204 TL16 Timer TL16 setting Sec.
DIGITAL INPUT: DIG INP
2501 SELBKDI1 Select blocking action by input DI1
2502 DI3 TRIP Configure trip outputs
2503 DI3 ALRM Configure alarm outputs
2504 DI3 TIMR Pickup Delay, DI3 timer sec.
2505 DI4 TRIP Configure trip outputs
2506 DI4 ALRM Configure alarm outputs
2507 DI4 TIMR Pickup delay, DI4 timer sec.
2508 DI6 FUNC Define DI6 Function
VOLTAGE TRANSFORMER FUSE FAILURE: VTFF
2601 VTFF Enable/Disable VTFF
ACCIDENTAL ENERGIZATION: AE
2701 TRIP Configure trip outputs
2702 ALARM Configure alarm outputs
2703 AE ARM Arming logic, Accidental Energization
GE Power Management DGP Digital Generator Protection System 2-
49
Page 90
2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
Table 2–6: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ABA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
GROUND OVERCURRENT: 51GN
2
2801 TRIP Configure trip outputs
2802 ALARM Configure alarm outputs
2803 PICKUP Pickup current Amps
2804 TIME FAC Time factor sec.
UNDERVOLTAGE: 27
2901 TRIP Configure trip outputs
2902 ALARM Configure alarm outputs
2903 PICKUP Pickup voltage (Positive sequence) Volts
2904 TIME FAC Time factor sec.
***
ABA SETTINGS TABLE (Sheet 5 of 5)
2905 CURVE # Curve number (1-Inverse, 2-Def. Time)
2-
50
DGP Digital Generator Protection System GE Power Management
Page 91
2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
2.4.3 DGP
Table 2–7: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ACA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
CONFIGURATION: CONFIG
101 UNITID Unit ID number
102 SYSFREQ System Frequency Hz
103 SEL TVM Select Trip Voltage Monitoring
104 SEL TCM Select Trip Current Monitoring
105 SELPRIM Select Primary/Secondary units
106 CT RATIO Current Transformer Ratio
107 VT RATIO Voltage Transformer Ratio
108 COMMPORT Communications Port
109 PHASE Phase Rotation
***
ACA SETTINGS TABLE (Sheet 1 of 6)
***
ACA SETTINGS TABLE
2
110 TIMESYNC Time Synchronizing source
111 NUM FLTS Number of Fault events stored
112 PREFLT Number of prefault cycles stored Cycles
113 OSC TRIG External oscillography trigger
114 NOM VOLT Nominal Voltage of generator Volts
115 RATEDCUR Rated Current of generator Amps
116 VT CONN Type of VT connection
117 NCTRATIO Current Transformer Ratio (Neutral)
STATOR DIFFERENTIAL: 87G
201 TRIP Configure trip outputs
202 ALARM Configure alarm outputs
203 K1 K factor %
204 PICKUP Pickup level Amps
CURRENT UNBALANCE – ALARM: 46A
301 ALARM Configure alarm outputs
302 PICKUP Pickup current (Negative sequence) Amps
303 TL14 Timer TL14 setting Sec.
GE Power Management DGP Digital Generator Protection System 2-
51
Page 92
2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
***
Table 2–7: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ACA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
ACA SETTINGS TABLE (Sheet 2 of 6)
2
CURRENT UNBALANCE – TRIP: 46T
401 TRIP Configure trip outputs
402 ALARM Configure alarm outputs
403 PICKUP Pickup current (Negative sequence) Amps
404 K2 K factor Sec.
LOSS OF EXCITATION – SUPERVISION: 40
501 SELV2SUP Select V2 supervision of 40
LOSS OF EXCITATION – ZONE 1: 40-1
601 TRIP Configure trip outputs
602 ALARM Configure alarm outputs
603 CENTER Center of characteristic Ohms
604 RADIUS Radius of characteristic Ohms
605 TL12 Timer TL12 setting Sec.
LOSS OF EXCITATION – ZONE 2: 40-2
701 TRIP Configure trip outputs
702 ALARM Configure alarm outputs
703 CENTER Center of characteristic Ohms
704 RADIUS Radius of characteristic Ohms
705 TL13 Timer TL13 setting Sec.
ANTI-MOTORING #1: 32-1
801 TRIP Configure trip outputs
802 ALARM Configure alarm outputs
803 SQ TR EN Enable sequential trip
804 REV PWR Reverse power pickup Watts
805 TL1 Timer TL1 setting Sec.
ANTI-MOTORING #2: 32-2
901 TRIP Configure trip outputs
902 ALARM Configure alarm outputs
903 REV PWR Reverse power pickup Watts
904 TL2 Timer TL2 setting Sec.
2-
52
DGP Digital Generator Protection System GE Power Management
Page 93
2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
Table 2–7: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ACA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
OVERCURRENT WITH VOLTAGE RESTRAINT: 51V
1001 TRIP Configure trip outputs
1002 ALARM Configure alarm outputs
1003 PICKUP Pickup current Amps
1004 TIME FAC Time factor Sec.
ST ATOR GROUND – ZONE 1: 64G1
1101 TRIP Configure trip outputs
1102 ALARM Configure alarm outputs
1103 PICKUP Pickup voltage Volts
1104 TL4 Timer TL4 setting Sec.
ST ATOR GROUND – ZONE 1: 64G2
1201 TRIP Configure trip outputs
***
ACA SETTINGS TABLE (Sheet 3 of 6)
2
1202 ALARM Configure alarm outputs
1203 TL5 Timer TL5 setting Sec.
OVEREXCITATION – ALARM: 24A
1301 ALARM Configure alarm outputs
1302 PICKUP Pickup (V/Hz) Per Unit
1303 TL6 Timer TL6 setting Sec.
OVEREXCITATION – TRIP: 24T
1401 TRIP ON Configure trip outputs (on-line)
1402 TRIP OFF Configure trip outputs (off-line)
1403 ALARM Configure alarm outputs
1404 CURVE # Curve number (Inverse characteristic)
1405 INV PU Pickup - V/Hz (Inverse characteristic) Per Unit
1406 TIME FAC Time factor Sec.
1407 INST PU Pickup - V/Hz (Instantaneous) Per Unit
1408 TL7 Timer TL7 setting Sec.
1409 RESET Reset time Sec.
OVERVOLTAGE: 59
1501 TRIP Configure trip outputs
GE Power Management DGP Digital Generator Protection System 2-
53
Page 94
2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
Table 2–7: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ACA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
1502 ALARM Configure alarm outputs
2
1503 PICKUP Inverse function pickup voltage (positive- sequence) Volts
1504 TIME FAC Time factor Sec.
1505 CURVE# Curve Number (1 = Inverse; 2 = Definite Time)
1506 INST PU Instantaneous Pickup Voltage (positive-sequence) Volts
OVER/UNDER FREQUENCY VOLTAGE CUTOFF: 81
1601 UVCUTOFF Undervoltage cutoff level for functions 81 Volts
UNDERFREQUENCY SETPOINT 1: 81-1U
1701 TRIP Configure trip outputs
1702 ALARM Configure alarm outputs
1703 SET PNT Set point Hz
1704 TL8 Timer TL8 setting Sec.
***
ACA SETTINGS TABLE (Sheet 4 of 6)
UNDERFREQUENCY SETPOINT 2: 81-2U
1801 TRIP Configure trip outputs
1802 ALARM Configure alarm outputs
1803 SET PNT Set point Hz
1804 TL9 Timer TL9 setting Sec.
UNDERFREQUENCY SETPOINT 3: 81-3U
1901 TRIP Configure trip outputs
1902 ALARM Configure alarm outputs
1903 SET PNT Set point Hz
1904 TL10 Timer TL10 setting Sec.
UNDERFREQUENCY SETPOINT 4: 81-4U
2001 TRIP Configure trip outputs
2002 ALARM Configure alarm outputs
2003 SET PNT Set point Hz
2004 TL11 Timer TL11 setting Sec.
OVERFREQUENCY SETPOINT 1: 81-1O
2101 TRIP Configure trip outputs
2102 ALARM Configure alarm outputs
2-
54
DGP Digital Generator Protection System GE Power Management
Page 95
2 CALCULATION OF SETTINGS 2.4 COMMISSIONING
Table 2–7: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ACA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
2103 SET PNT Set point Hz
2104 TL15 Timer TL15 setting Sec.
OVERFREQUENCY SETPOINT 2: 81-2O
2201 TRIP Configure trip outputs
2202 ALARM Configure alarm outputs
2203 SET PNT Set point Hz
2204 TL16 Timer TL16 setting Sec.
OVERFREQUENCY SETPOINT 3: 81-3O
2301 TRIP Configure trip outputs
2302 ALARM Configure alarm outputs
2303 SET PNT Set point Hz
2304 TL17 Timer TL17 setting Sec.
***
ACA SETTINGS TABLE (Sheet 5 of 6)
2
OVERFREQUENCY SETPOINT 4: 81-4O
2401 TRIP Configure trip outputs
2402 ALARM Configure alarm outputs
2403 SET PNT Set point Hz
2404 TL18 Timer TL18 setting Sec.
DIGITAL INPUT: DIG INP
2501 SELBKDI1 Select blocking action by input DI1
2502 DI3 TRIP Configure trip outputs
2503 DI3 ALRM Configure alarm outputs
2504 DI3 TIMR Pickup Delay, DI3 timer sec.
2505 DI4 TRIP Configure trip outputs
2506 DI4 ALRM Configure alarm outputs
2507 DI4 TIMR Pickup delay, DI4 timer sec.
2508 DI6 FUNC Define DI6 Function
VOLTAGE TRANSFORMER FUSE FAILURE: VTFF
2601 VTFF Enable/Disable VTFF
ACCIDENTAL ENERGIZATION: AE
2701 TRIP Configure trip outputs
GE Power Management DGP Digital Generator Protection System 2-
55
Page 96
2.4 COMMISSIONING 2 CALCULATION OF SETTINGS
***
Table 2–7: DGP
LOCATION: GENERATOR NUMBER:
RELAY MODEL NUMBER: DGP _ _ _ ACA PROM VERSION NUMBER: V _ _ _ . _ _ _ _ _ D
SETTING # MNEMONIC DESCRIPTION USER SETTING
ACA SETTINGS TABLE (Sheet 6 of 6)
2
2702 ALARM Configure alarm outputs
2703 AE ARM Arming logic, Accidental Energization
GROUND OVERCURRENT: 51GN
2801 TRIP Configure trip outputs
2802 ALARM Configure alarm outputs
2803 PICKUP Pickup current Amps
2804 TIME FAC Time factor sec.
UNDERVOLTAGE: 27
2901 TRIP Configure trip outputs
2902 ALARM Configure alarm outputs
2903 PICKUP Pickup voltage (Positive sequence) Volts
2904 TIME FAC Time factor sec.
2905 CURVE # Curve number (1-Inverse, 2-Def. Time)
UNDERVOLTAGE – THIRD HARMONIC: 27TN
3001 TRIP Configure trip outputs
3002 ALARM Configure alarm outputs
3003 PICKUP Pickup voltage (3rd Harmonic at generator neutral) Volts
3004 TL20 Timer TL20 setting Sec.
3005 FORPWR-L Lower limit of Forward Power window Watts
3006 FORPWR-H Upper limit of Forward Power window Watts
2-
56
DGP Digital Generator Protection System GE Power Management
Page 97
3 HARDWARE DESCRIPTION 3.1 CASE ASSEMBLY
3 HARDWARE DESCRIPTION 3.1 CASE ASSEMBLY 3.1.1 WARNING
Power down the relay by removing one of the connection plugs or turn both power switches
to OFF before removng or inserting modules. Failure to do so can permanently damage the
CAUTION
The case that houses the electronic modules is constructed from an aluminum alloy. It consists of a main frame
with side mounting brackets, a front cover and a rear cover.
The front cover, comprised of a metal frame with pl ate gl as s, is pivote d on th e top a nd is ope ned fro m the bottom by way of two spring-loaded latches. The door is constrained from coming off by tabs that require the door
to be unlatched and lifted slightly to be removed. A push-button extender installed into the plate glass makes it
possible to clear the display without removing the front cover.
The rear cover supports terminal blocks that are us ed in making extern al connections to the cas e. The modules are mounted ve rti c ally in si de t he c as e and ar e s up ported by sockets on the m otherboard within the c ase .
In addition to providing th is mec ha nic al su ppo rt, the so ck et s al so o ffer the me ans of making the electrical connection to the modules. The modules are further restrained inside the case by the front cover.
Proper alignment of the module with respec t to the socket is mainta ined by slotted guides, on e guide above
and one guide beneat h each module, with the exception of the magnetics module , MGM and MMI modul es,
which require two guides above and two beneath.
relay.
3.1.2 CONSTRUCTION
3
3.1.3 ELECTRICAL CONNECTIONS & INTERNAL WIRING
As mentioned earli er, electrical connections are made to the case through e ight terminal blo cks mounted on
the rear cover plat e. Each block cont ains 14 termina l points, which con sist of a #6 screw threaded into a fla t
contact plate.
specifications for two wires per terminal.
Connection to the MGM module is made by means of two connector sockets: an 8-contact current block and a
104-pin signal b lock. The curren t block contacts a re rated to hand le current transfor mer (CT) second ary currents. They are shorted upon removal of the MGM module.
The DGP model num ber label is located on the o utside of the front cover and on the right-hand sidesheet
inside the case. A mar king str ip in dicati ng the nam e and pos ition of every mo dule in a case is incl uded on th e
front center of the case. It is placed to be read when the front cover is removed.
The terminal blocks lo cated on the rear co ver plate are unique ly identified by a two-letter code fou nd directly
beneath the outermost ed ge of each termin al block. Also, the ter minal points (1 t hrough 14) are ide ntified by
stamped numbers.
Connector PL1 is used for serial communication between the DGP and the PC/Modem. Connector PL2 is used
to output sequence of events (SOE) to a serial printer or a DEC100 unit for additional auxiliary contacts output.
PL3 is used for IRIG-B signal inp ut to the DGP. N ote that t he PL2 and PL3 conne ctors a re not incl uded on all
DGP models; see Section 1.1.2: ORDER CODES & SELECTION GUIDE on page 1–2 for details.
Each terminal is rated for a maximum of two connections. Exceeding this will violate UL
3.1.4 IDENTIFICATION
GE Power Management DGP Digital Generator Protection System 3-
1
Page 98
3.1 CASE ASSEMBLY 3 HARDWARE DESCRIPTION
DIA.
(TYPICAL)
.281 DIA..281
4.00
(102mm)
(74.6mm)
2.938
(102mm)
4.00
3
(26mm)
TO
ALLOW
.375(9.5mm)
MINIIMUM TOMINIIMUM
ALSO ALLOWALSO
18.375
CABLE
MINIMUM
REMOVE CABLEREMOVE
(467mm)
3.00
13.031
(332mm)
.344
(76.0mm)
(8.7mm)
PLUG
*
CUTOUT
13.938
(354mm)
REQD.
WHEN
* WHEN REQD.*
13.875
(352.4mm)
TERMINIAL
BLOCKS
(TYPICAL)
LATCH
1.00
(26mm)
.313(7.9mm)
17.25
(438mm)
MOUNTING
PANEL DRILLING
PANEL
AND
FOR PANEL MOUNTINGFOR
CUTOUT AND PANEL DRILLINGCUTOUT
VIEW
SIDE VIEWSIDE
3-
17.001.00 1.00
(432mm)
VIEW
PLAN
18.375
(467mm)
ARE
X
SLOTS
19.00
VIEW
(483mm)
FRONT VIEWFRONT
(26mm)
PARTIAL PLAN VIEWPARTIAL
.344
(8.7mm)
1.469
(37mm)
4.00
(102mm)
2.938
(74.6mm)
.406(10.3mm) X.406(10.3mm)
.281(7.1mm)
MOUNTING SLOTS AREMOUNTING
4.00
(102mm)
1.469
(37mm)
Figure 3–1: DGP OUTLINE DRAWING
2
DGP Digital Generator Protection System GE Power Management
Page 99
3 HARDWARE DESCRIPTION 3.1 CASE ASSEMBLY
MAN MACHINE INTERFACE MODULE (MMI)
n
16 digit alpha-numeric LED display for fault report,
metering values, alarm messages, setting parameters, etc.
n
keypad includes 20 keys for user friendly
local interface with the DGP
n
dual color LED indicates relay status
n
RS232 port facilitates connection of lap-top PC
MODULES
POWER SUPPLY MODULES
are located behind the
cover plate. Module PS2
is optional
DIGITAL INPUT & TARGET
MODULE (DIT) LED targets
indicate ALL the fuctions
that operated during a
trip event
MAGNETIC MODULES
(MGM) Two identical
modules contain CT's, VT's,
output relays, etc. and are
interchangeable.
MMI301
GREEN: PROTECTION ON
57C
57B
57A
51V-C
51V-B
51V-A
24C
24B
24A
40G2
40G1
64G2
64G1
81-O
81-U
32
59
46
VTFF
PS1 PS2
PS1 PS2
TPM1 MGM781 MGM781 TPM2
1 115
15
16
2 216
17
DIT101
DIT101 MMI301 SSP301 ANI301 DAP201 DSP401
RED: CHECK STATUS
F LT T Y PE : B
CLR
3/N
2
SET
1/V
6
5
INF
4
9
8
7
ACT
ENT
0
PRT
END
MMI301 SSP301 ANI301 DAP201 DSP401
17
System Processor (SSP),
Analog Interface (ANI),
Data Acquisition (DAP), &
Digital Signal Processor
(DSP) modules are plug-in
type for ease of maintenance
and trouble-shooting.
3
OPTIONAL TEST BLOCKS
facilitate injection of
analog input signals and
monitoring of DGP outputs
for test purpose without
disturbing field wiring.
OUTPUT RELAY CONTACTS
n
8 configurable relays
n
8 predefined relays
CONTROL POWER
DC control power input
CT INPUTS
n
6 phase CT inputs
n
1 residual CT input
n
1 residual/neutral CT input
RATINGS
IN 5 AMP
VN 100/140 VOLTS
FREQ 50/60 Hz
RS232 PLUG (PL-1)
provides connection to modem
for remote communications
or an interface to station
integration system.
PL-1 PL-2 PL-3
AE
AF
AG
AH
RATINGS
IN 5 AMP
VN 100/140 VOLTS
FREQ 50/60 Hz
OPTIONAL SERIAL PORT (PL-2)
Can be used to connect a
printer for automatic/manual
printout of data or a Contact
Expansion Unit DEC1000.
BE
BF
BG
BH
1111
1212
2727 1313
2828
1414
OPTIONAL PLUG (PL-3)
Available for IRIG-B signal input
to synchronize the DGP internal
clock to a common reference
clock e.g. GPS receiver.
DIGITAL INPUTS:
n
3 configurable contact
inputs
n
3 predefined contact
inputs
VT INPUTS:
n
3 phase vt inputs,
wye or delta
n
1 neutral vt input
704752A8.CDR
Figure 3–2: FRONT AND REAR VIEW
GE Power Management DGP Digital Generator Protection System 3-
3
Page 100
3.2 CIRCUIT BOARD MODULES 3 HARDWARE DESCRIPTION
3.2 CIRCUIT BOARD MODULES 3.2.1 WARNING
This relay contains electronic components that could be damaged by electrostatic discharge
currents. The main source of electrostatic discharge currents is the human body , and the con-
CAUTION
Each module consis ts of a printed-circuit boar d an d fron t panel. Two knobs are provided on the fron t panel for
3
removing and inser ting the module. Electrical c onnection is made by the 96 pin s of the Eurocard connector
located at the back of the board.
Each module has it s o w n id ent ifi ca tio n nu mbe r, consisting of a three -l ett er co de fo ll owed by a thr ee -dig it nu mber. These are found at the bottom of each front panel.
ditions of low humidity, carpeted floors, and isolating shoes are conducive to the generation
of electrostatic discharge currents. Where these conditions exist, care must be exercised
when removing and/or handling the modules. The persons handling the modules must ensure
that their body charge has been discharged by touching some surface at ground potential
before touching any of the components on the modules.
3.2.2 BASIC CONSTRUCTION
3.2.3 IDENTIFICATION
3-
Figure 3–3: DGP POWER SUPPLY MODULE
4
DGP Digital Generator Protection System GE Power Management
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